Approval, Disapproval and Promulgation of Implementation Plans; State of Wyoming; Regional Haze State Implementation Plan; Federal Implementation Plan for Regional Haze, 5031-5222 [2014-00930]
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Vol. 79
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January 30, 2014
Part II
Environmental Protection Agency
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40 CFR Part 52
Approval, Disapproval and Promulgation of Implementation Plans; State of
Wyoming; Regional Haze State Implementation Plan; Federal
Implementation Plan for Regional Haze; Final Rule
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Federal Register / Vol. 79, No. 20 / Thursday, January 30, 2014 / Rules and Regulations
ENVIRONMENTAL PROTECTION
AGENCY
40 CFR Part 52
[EPA–R08–OAR–2012–0026, FRL9905–42–
R08]
Approval, Disapproval and
Promulgation of Implementation Plans;
State of Wyoming; Regional Haze State
Implementation Plan; Federal
Implementation Plan for Regional Haze
Environmental Protection
Agency.
ACTION: Final rule.
AGENCY:
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Definitions
The Environmental Protection
Agency (EPA) is partially approving and
partially disapproving a State
Implementation Plan (SIP) submitted by
the State of Wyoming on January 12,
2011, that addresses regional haze. This
SIP was submitted to address the
requirements of the Clean Air Act (CAA
or ‘‘the Act’’) and rules that require
states to address in specific ways any
existing anthropogenic impairment of
visibility in mandatory Class I areas
caused by emissions of air pollutants
from numerous sources located over a
wide geographic area (also referred to as
the ‘‘regional haze program’’). States are
required to assure reasonable progress
toward the national goal of achieving
natural visibility conditions in Class I
areas. EPA is approving several aspects
of Wyoming’s regional haze SIP that we
had proposed to disapprove in our June
10, 2013 proposed rule in light of public
comments and newly available
information indicating the adequacy of
the SIP with respect to those aspects.
EPA is also approving some aspects of
the State’s SIP that we proposed to
approve. EPA is promulgating a Federal
Implementation Plan (FIP) to address
some of the deficiencies identified in
our proposed partial disapproval of
Wyoming’s regional haze SIP issued on
June 10, 2013. EPA is taking this action
pursuant to sections 110 and 169A of
the CAA.
DATES: This final rule is effective March
3, 2014.
ADDRESSES: EPA has established a
docket for this action under Docket ID
No. EPA–R08–OAR–2012–0026. All
documents in the docket are listed on
the www.regulations.gov Web site.
Publicly available docket materials
are available either electronically
through www.regulations.gov, or in hard
copy at the Air Program, Environmental
Protection Agency (EPA), Region 8,
1595 Wynkoop Street, Denver, Colorado
80202–1129. EPA requests that if, at all
possible, you contact the individual
listed in the FOR FURTHER INFORMATION
SUMMARY:
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CONTACT section to view the hard copy
of the docket. You may view the hard
copy of the docket Monday through
Friday, 8 a.m. to 4 p.m., excluding
Federal holidays.
FOR FURTHER INFORMATION CONTACT:
Laurel Dygowski, Air Program,
Mailcode 8P–AR, Environmental
Protection Agency, Region 8, 1595
Wynkoop Street, Denver, Colorado
80202–1129, (303) 312–6144,
dygowski.laurel@epa.gov.
SUPPLEMENTARY INFORMATION:
For the purpose of this document, we
are giving meaning to certain words or
initials as follows:
i. The words or initials Act or CAA mean
or refer to the Clean Air Act, unless the
context indicates otherwise.
ii. The initials AFUDC mean or refer to
Allowance for Funds Utilized During
Construction.
iii. The initials APA mean or refer to the
Administrative Procedures Act.
iv. The initials AQRV mean or refer to Air
Quality Related Value.
v. The initials BACT mean or refer to Best
Available Control Technology.
vi. The initials BART mean or refer to Best
Available Retrofit Technology.
vii. The initials CAMD mean or refer to
Clean Air Markets Division.
viii. The initials CAMx mean or refer to
Comprehensive Air Quality Model.
ix. The initials CCM mean or refer to EPA’s
Control Cost Manual.
x. The initials CLRC mean or refer to the
Construction Labor Research Council.
xi. The initials CMAQ mean or refer to
Community Multi-Scale Air Quality
modeling system.
xii. The initials CSAPR mean or refer to the
Cross-State Air Pollution Rule.
xiii. The initial DEQ mean or refer to the
Wyoming Department of Environmental
Quality.
xiv. The initials EGUs mean or refer to
Electric Generating Units.
xv. The initials EIS mean or refer to
Environmental Impact Statement.
xvi. The words EPA, we, us or our mean
or refer to the United States Environmental
Protection Agency.
xvii. The initials ESP mean or refer to
electrostatic precipitator.
xviii. The initials FIP mean or refer to
Federal Implementation Plan.
xix. The initials FLM mean or refer to
Federal Land Managers.
xx. The initials FR mean or refer to the
Federal Register.
xxi. The initials GAQM mean or refer to
Guidance on Air Quality Models.
xxii. The initials IMPROVE mean or refer
to Interagency Monitoring of Protected Visual
Environments monitoring network.
xxiii. The initials IPM mean or refer to
Integrated Planning Model.
xxiv. The initials IWAQM mean or refer to
Interagency Workgroup on Air Quality
Modeling.
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xxv. The initials LNB mean or refer to low
NOX burners.
xxvi. The initials LRS mean or refer to
Laramie River Station.
xxvii. The initials LTS mean or refer to
long term strategy.
xxviii. The initials MATS mean or refer to
the Mercury and Air Toxics Standard.
xxix. The initials MW mean or refer to
megawatts.
xxx. The initials NAAQS mean or refer to
National Ambient Air Quality Standards.
xxxi. The initials NEPA mean or refer to
National Environmental Policy Act.
xxxii. The initials NH 3 mean or refer to
ammonia.
xxxiii. The initials NO X mean or refer to
nitrogen oxides.
xxxiv. The initials OFA mean or refer to
overfire air.
xxxv. The initials PM mean or refer to
particulate matter.
xxxvi. The initials PM 2.5 mean or refer to
particulate matter with an aerodynamic
diameter of less than 2.5 micrometers.
xxxvii. The initials PM 10 mean or refer to
particulate matter with an aerodynamic
diameter of less than 10 micrometers.
xxxviii. The initials PTE mean or refer to
potential to emit.
xxxix. The initials RAVI mean or refer to
reasonably attributable visibility impairment.
xl. The initials RHR mean or refer to the
Regional Haze Rule.
xli. The initials RIS mean or refer to
Regulatory Impact Statement.
xlii. The initials RPG mean or refer to
reasonable progress goals.
xliii. The initials RPO mean or refer to
Regional Planning Organization.
xliv. The initials SCR mean or refer to
selective catalytic reduction.
xlv. The initials SIP mean or refer to State
Implementation Plan.
xlvi. The initials SNCR mean or refer to
selective non-catalytic reduction.
xlvii. The initials SO 2 mean or refer to
sulfur dioxide.
xlviii. The initials SOFA mean or refer to
separated overfire air.
xlix. The initials UMRA mean or refer to
the Unfunded Mandates Reform Act.
l. The initials URP mean or refer to
Uniform Rate of Progress.
li. The initials VOC mean or refer to
volatile organic compounds.
lii. The initials WAQSR mean or refer to
the Wyoming Air Quality Standards and
Regulations.
liii. The initials WRAP mean or refer to the
Western Regional Air Partnership.
liv. The words Wyoming and State mean
the State of Wyoming.
Table of Contents
I. Background
A. Regional Haze
i. Requirements of the CAA and EPA’s
Regional Haze Rule (RHR)
ii. Roles of Agencies in Addressing
Regional Haze
B. Requirements for the Regional Haze SIPs
i. The CAA and the Regional Haze Rule
ii. Determination of Baseline, Natural, and
Current Visibility Conditions
iii. Determination of Reasonable Progress
Goals
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iv. Best Available Retrofit Technology
v. Long-Term Strategy
vi. Coordinating Regional Haze and
Reasonably Attributable Visibility
Impairment
vii. Monitoring Strategy and Other
Implementation Plan Requirements
viii. Consultation With States and Federal
Land Managers (FLMs)
C. Our Proposal
D. Public Participation
II. Final Action
III. Changes From Proposed Rule and
Reasons for Changes
A. Changes to Proposed Costs and
Visibility Improvements
B. Changes to Our Proposed
Determinations
1. Dave Johnston Unit 3
2. Dave Johnston Unit 4
3. Naughton Units 1 and 2
4. Naughton Unit 3
5. Wyodak
6. Jim Bridger
7. Dave Johnston Units 1 and 2
IV. Basis for Our Final Action
A. Laramie River
B. Jim Bridger
C. Dave Johnston Units 3 and 4
D. Naughton
E. Wyodak
F. Dave Johnston Units 1 and 2 (Reasonable
Progress)
V. Issues Raised by Commenters and EPA’s
Responses
A. Legal Issues
1. EPA Authority and State Discretion
2. Compliance With Section 307(d)
3. Compliance With Section 169A(d)
4. Public Hearings
5. RHR and BART Guidelines
6. Reasonableness Standard
7. Reliance on Emission Reductions
8. Presumptive Limits
9. Compliance With 40 CFR 51.308
10. Legal Analysis
11. Consideration of Existing Controls
12. Consent Decree
13. Monitoring, Recordkeeping and
Reporting
B. Modeling
1. General Comments
2. EPA Modeling
a. Description of Revised EPA Modeling
b. Comments on EPA Modeling
C. Overarching Comments on BART
1. BART-Eligible Sources
2. Cost of Controls
3. Consideration of the Five Factors
4. Visibility Improvement
5. PM BART Determinations
6. Incremental Costs and Visibility
7. Other Comments on BART
D. BART Sources
1. Basin Electric Laramie River Station
Units 1–3
a. General Comments
b. NOX BART Determination
2. Jim Bridger Units 1–4
a. NOX BART Determination
b. PM BART Determination
3. Dave Johnston Unit 3 and Unit 4
a. NOX BART Determination
b. Alternative Control Technology Proposal
4. Naughton Units 1–3
a. NOX BART Determination
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b. Alternative Control Technology Proposal
5. Wyodak
6. Trona Mines
a. FMC Westvaco and General Chemical
Green River
b. FMC Granger Trona Mine
E. Reasonable Progress
1. RPGs
2. Reasonable Progress Sources
a. Oil and Gas Sources
b. Dave Johnston Unit 1 and Unit 2
F. General Comments
1. Replacement of FIP Elements With SIP
2. Public Comment
3. Economic Concerns
4. National Ambient Air Quality Standards
(NAAQS)
5. Other
VI. Non-Relevant Comments From EPA’s
Original June 4, 2012 Proposal
A. General Comments
B. Basin Electric Laramie River
C. Jim Bridger Units 1–4
D. Dave Johnston Units 3 and 4
E. Naughton Units 1–3
F. Wyodak
G. Dave Johnston Units 1 and 2
H. Modeling
VII. Statutory and Executive Order Reviews
I. Background
The CAA requires each state to
develop plans, referred to as SIPs, to
meet various air quality requirements. A
state must submit its SIP and SIP
revisions to us for approval. Once
approved, a SIP is enforceable by EPA
and citizens under the CAA, also known
as being federally enforceable. If a state
fails to make a required SIP submittal or
if we find that a state’s required
submittal is incomplete or
unapprovable, then we must promulgate
a FIP to fill this regulatory gap. CAA
section 110(c)(1). This action involves
the requirement that states have SIPs
that address regional haze.
Few states submitted a regional haze
SIP prior to the December 17, 2007
deadline, and on January 15, 2009, EPA
found that 37 states, including
Wyoming,1 the District of Columbia,
and the Virgin Islands, had failed to
submit SIPs addressing the regional
haze requirements. 74 FR 2392. Once
EPA has found that a state has failed to
make a required submission, EPA is
required to promulgate a FIP within two
years unless the state submits a SIP and
the Agency approves it within the twoyear period. CAA section 110(c)(1).
Wyoming subsequently submitted a SIP
1 We issued a finding of failure to submit for
Wyoming only for the requirements of 40 CFR
51.309(g)) regarding required SIP provisions,
including NOX BART, to address visibility at Class
I areas other than the 16 areas covered by the Grand
Canyon Visibility Transport Commission Report.
Wyoming had submitted a SIP for the rest of the
requirements under 40 CFR 51.309 prior to our
January 15, 2009 finding.
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addressing regional haze on January 12,
2011.
States in the west were given the
option to meet the requirements of the
RHR either under 40 CFR 51.309 or 40
CFR 51.308. Wyoming chose to adopt
the requirements of 40 CFR 51.309.
Section 309 requires states to adopt
regional haze strategies that are based
on recommendations from the Grand
Canyon Visibility Transport
Commission for protecting the 16 Class
I areas in the Colorado Plateau area,
including a sulfur dioxide (SO2)
backstop cap and trade program, SO2
milestones, and other requirements such
as smoke management, a program to
address mobile sources, and pollution
prevention. Also, section 309(g)
includes requirements for SIP
provisions, including NOX BART, to
address visibility impairment at other
Class I areas. On December 12, 2012, we
finalized approval of Wyoming’s 309
regional haze SIP for the requirements
relating to the SO2 backstop cap and
trade program, milestones and the other
requirements.2 Today’s action addresses
the remaining portion of Wyoming’s
SIP, including the Best Available
Retrofit Technology (BART)
determinations for nitrogen oxides
(NOX) and particulate matter (PM).
In a lawsuit in the U.S. District Court
for the District of Colorado,
environmental groups sued EPA for our
failure to take timely action with respect
to the regional haze requirements of the
CAA and our regulations.3 In particular,
the lawsuits alleged that we had failed
to promulgate FIPs for these
requirements within the two-year period
allowed by CAA section 110(c) or, in the
alternative, fully approve SIPs
addressing these requirements.
As a result of these lawsuits, we
entered into a consent decree. The
consent decree requires that we sign a
notice of final rulemaking addressing
the regional haze requirements for
Wyoming by January 10, 2014.4 We are
meeting that requirement with the
signing of this final rule
A. Regional Haze
Regional haze is visibility impairment
that is produced by a multitude of
sources and activities which are located
across a broad geographic area and emit
fine particles (PM2.5) (e.g., sulfates,
nitrates, organic carbon (OC), elemental
carbon (EC), and soil dust), and their
precursors (e.g., sulfur dioxide (SO2),
2 77
FR 73926 (Dec. 12, 2012).
Guardians v. Jackson, 1:11–cv–CMA–
MEH (D. Colo.).
4 WildEarth Guardians v. Jackson, 1:11–cv–CMA–
MEH (D. Colo.) (Dkt. Nos. 73, 74).
3 WildEarth
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NOX, and in some cases, ammonia (NH3)
and volatile organic compounds (VOC)).
Fine particle precursors react in the
atmosphere to form PM2.5, which
impairs visibility by scattering and
absorbing light. Visibility impairment
reduces the clarity, color, and visible
distance that one can see. PM2.5 can also
cause serious health effects and
mortality in humans and contributes to
environmental effects such as acid
deposition and eutrophication.
Data from the existing visibility
monitoring network, the ‘‘Interagency
Monitoring of Protected Visual
Environments’’ (IMPROVE) monitoring
network, show that visibility
impairment caused by air pollution
occurs virtually all the time at most
national park and wilderness areas. The
average visual range 5 in many Class I
areas (i.e., national parks and memorial
parks, wilderness areas, and
international parks meeting certain size
criteria) in the western United States is
100–150 kilometers, or about one-half to
two-thirds of the visual range that
would exist without anthropogenic air
pollution. In most of the eastern Class
I areas of the United States, the average
visual range is less than 30 kilometers,
or about one-fifth of the visual range
that would exist under estimated
natural conditions. 64 FR 35715 (July 1,
1999).
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i. Requirements of the CAA and EPA’s
Regional Haze Rule (RHR)
In section 169A of the 1977
Amendments to the CAA, Congress
created a program for protecting
visibility in the nation’s national parks
and wilderness areas. This section of the
CAA establishes as a national goal the
‘‘prevention of any future, and the
remedying of any existing, impairment
of visibility in mandatory Class I
Federal areas 6 which impairment
5 Visual range is the greatest distance, in
kilometers or miles, at which a dark object can be
viewed against the sky.
6 Areas designated as mandatory Class I Federal
areas consist of national parks exceeding 6000
acres, wilderness areas and national memorial parks
exceeding 5000 acres, and all international parks
that were in existence on August 7, 1977. 42 U.S.C.
7472(a). In accordance with section 169A of the
CAA, EPA, in consultation with the Department of
Interior, promulgated a list of 156 areas where
visibility is identified as an important value. 44 FR
69122 (November 30, 1979). The extent of a
mandatory Class I area includes subsequent changes
in boundaries, such as park expansions. 42 U.S.C.
7472(a). Although states and tribes may designate
as Class I additional areas which they consider to
have visibility as an important value, the
requirements of the visibility program set forth in
section 169A of the CAA apply only to ‘‘mandatory
Class I Federal areas.’’ Each mandatory Class I
Federal area is the responsibility of a ‘‘Federal Land
Manager.’’ 42 U.S.C. 7602(i). When we use the term
‘‘Class I area’’ in this action, we mean a ‘‘mandatory
Class I Federal area.’’
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results from manmade air pollution.’’
On December 2, 1980, EPA promulgated
regulations to address visibility
impairment in Class I areas that is
‘‘reasonably attributable’’ to a single
source or small group of sources, i.e.,
‘‘reasonably attributable visibility
impairment.’’ 45 FR 80084. These
regulations represented the first phase
in addressing visibility impairment.
EPA deferred action on regional haze
that emanates from a variety of sources
until monitoring, modeling and
scientific knowledge about the
relationships between pollutants and
visibility impairment were improved.
Congress added section 169B to the
CAA in 1990 to address regional haze
issues. EPA promulgated a rule to
address regional haze on July 1, 1999.
64 FR 35714 (July 1, 1999), codified at
40 CFR part 51, subpart P. The RHR
revised the existing visibility
regulations to integrate into the
regulation provisions addressing
regional haze impairment and
established a comprehensive visibility
protection program for Class I areas. The
requirements for regional haze, found at
40 CFR 51.308 and 51.309, are included
in EPA’s visibility protection
regulations at 40 CFR 51.300–51.309.
Some of the main elements of the
regional haze requirements are
summarized in section III of this
preamble. The requirement to submit a
regional haze SIP applies to all 50 states,
the District of Columbia and the Virgin
Islands. 40 CFR 51.308(b) requires states
to submit the first implementation plan
addressing regional haze visibility
impairment no later than December 17,
2007.7
Few states submitted a regional haze
SIP prior to the December 17, 2007
deadline, and on January 15, 2009, EPA
found that 37 states (including
Wyoming), the District of Columbia, and
the Virgin Islands, had failed to submit
SIPs addressing the regional haze
requirements. 74 FR 2392. Once EPA
has found that a state has failed to make
a required submission, EPA is required
to promulgate a FIP within two years
unless the state submits a SIP and the
Agency approves it within the two-year
period. CAA section110(c)(1).
ii. Roles of Agencies in Addressing
Regional Haze
Successful implementation of the
regional haze program will require longterm regional coordination among
states, tribal governments, and various
federal agencies. As noted above,
7 EPA’s regional haze regulations require
subsequent updates to the regional haze SIPs. 40
CFR 51.308(g)–(i).
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pollution affecting the air quality in
Class I areas can be transported over
long distances, even hundreds of
kilometers. Therefore, to effectively
address the problem of visibility
impairment in Class I areas, states need
to develop strategies in coordination
with one another, taking into account
the effect of emissions from one
jurisdiction on the air quality in
another.
Because the pollutants that lead to
regional haze can originate from sources
located across broad geographic areas,
EPA has encouraged the states and
tribes across the United States to
address visibility impairment from a
regional perspective. Five regional
planning organizations (RPOs) were
developed to address regional haze and
related issues. The RPOs first evaluated
technical information to better
understand how their states and tribes
impact Class I areas across the country,
and then pursued the development of
regional strategies to reduce emissions
of pollutants that lead to regional haze.
The Western Regional Air Partnership
(WRAP) RPO is a collaborative effort of
state governments, tribal governments,
and various federal agencies established
to initiate and coordinate activities
associated with the management of
regional haze, visibility and other air
quality issues in the western United
States. WRAP member state
governments include: Alaska, Arizona,
California, Colorado, Idaho, Montana,
New Mexico, North Dakota, Oregon,
South Dakota, Utah, Washington, and
Wyoming. Tribal members include
Campo Band of Kumeyaay Indians,
Confederated Salish and Kootenai
Tribes, Cortina Indian Rancheria, Hopi
Tribe, Hualapai Nation of the Grand
Canyon, Native Village of Shungnak,
Nez Perce Tribe, Northern Cheyenne
Tribe, Pueblo of Acoma, Pueblo of San
Felipe, and Shoshone-Bannock Tribes of
Fort Hall.
B. Requirements for Regional Haze SIPs
The following is a summary of the
requirements of the RHR. See 40 CFR
51.308 for further detail regarding the
requirements of the rule.
i. The CAA and the Regional Haze Rule
Regional haze SIPs must assure
reasonable progress towards the
national goal of achieving natural
visibility conditions in Class I areas.
Section 169A of the CAA and EPA’s
implementing regulations require states
to establish long-term strategies for
making reasonable progress toward
meeting this goal. Implementation plans
must also give specific attention to
certain stationary sources that were in
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existence on August 7, 1977, but were
not in operation before August 7, 1962,
and require these sources, where
appropriate, to install BART controls for
the purpose of eliminating or reducing
visibility impairment. The specific
regional haze SIP requirements are
discussed in further detail below.
ii. Determination of Baseline, Natural,
and Current Visibility Conditions
The RHR establishes the deciview as
the principal metric or unit for
expressing visibility. See 70 FR 39104,
39118. This visibility metric expresses
uniform changes in the degree of haze
in terms of common increments across
the entire range of visibility conditions,
from pristine to extremely hazy
conditions. Visibility expressed in
deciviews is determined by using air
quality measurements to estimate light
extinction and then transforming the
value of light extinction using a
logarithmic function. The deciview is a
more useful measure for tracking
progress in improving visibility than
light extinction itself because each
deciview change is an equal incremental
change in visibility perceived by the
human eye. Most people can detect a
change in visibility at one deciview.8
The deciview is used in expressing
RPGs (which are interim visibility goals
towards meeting the national visibility
goal), defining baseline, current, and
natural conditions, and tracking changes
in visibility. The regional haze SIPs
must contain measures that ensure
‘‘reasonable progress’’ toward the
national goal of preventing and
remedying visibility impairment in
Class I areas caused by anthropogenic
air pollution by reducing anthropogenic
emissions that cause regional haze. The
national goal is a return to natural
conditions, i.e., anthropogenic sources
of air pollution would no longer impair
visibility in Class I areas.
To track changes in visibility over
time at each of the 156 Class I areas
covered by the visibility program (40
CFR 81.401–437), and as part of the
process for determining reasonable
progress, states must calculate the
degree of existing visibility impairment
at each Class I area at the time of each
regional haze SIP submittal and
periodically review progress every five
years midway through each 10-year
implementation period. To do this, the
RHR requires states to determine the
degree of impairment (in deciviews) for
the average of the 20 percent least
impaired (‘‘best’’) and 20 percent most
8 The preamble to the RHR provides additional
details about the deciview. 64 FR 35714, 35725
(July 1, 1999).
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impaired (‘‘worst’’) visibility days over
a specified time period at each of their
Class I areas. In addition, states must
also develop an estimate of natural
visibility conditions for the purpose of
comparing progress toward the national
goal. Natural visibility is determined by
estimating the natural concentrations of
pollutants that cause visibility
impairment and then calculating total
light extinction based on those
estimates. We have provided guidance
to states regarding how to calculate
baseline, natural and current visibility
conditions.9
For the first regional haze SIPs that
were due by December 17, 2007,
‘‘baseline visibility conditions’’ were the
starting points for assessing ‘‘current’’
visibility impairment. Baseline visibility
conditions represent the degree of
visibility impairment for the 20 percent
least impaired days and 20 percent most
impaired days for each calendar year
from 2000 to 2004. Using monitoring
data for 2000 through 2004, states are
required to calculate the average degree
of visibility impairment for each Class I
area, based on the average of annual
values over the five-year period. The
comparison of initial baseline visibility
conditions to natural visibility
conditions indicates the amount of
improvement necessary to attain natural
visibility, while the future comparison
of baseline conditions to the then
current conditions will indicate the
amount of progress made. In general, the
2000–2004 baseline period is
considered the time from which
improvement in visibility is measured.
iii. Determination of Reasonable
Progress Goals
The vehicle for ensuring continuing
progress towards achieving the natural
visibility goal is the submission of a
series of regional haze SIPs from the
states that establish two RPGs (i.e., two
distinct goals, one for the ‘‘best’’ and
one for the ‘‘worst’’ days) for every Class
I area for each (approximately) 10-year
implementation period. See 40 CFR
51.308(d), (f). The RHR does not
mandate specific milestones or rates of
progress, but instead calls for states to
establish goals that provide for
‘‘reasonable progress’’ toward achieving
9 Guidance for Estimating Natural Visibility
Conditions Under the Regional Haze Rule,
September 2003, EPA–454/B–03–005, available at
https://www.epa.gov/ttncaaa1/t1/memoranda/
Regional_Haze_envcurhr_gd.pdf, (hereinafter
referred to as ‘‘our 2003 Natural Visibility
Guidance’’); and Guidance for Tracking Progress
Under the Regional Haze Rule, (September 2003,
EPA–454/B–03–004, available at https://
www.epa.gov/ttncaaa1/t1/memoranda/rh_tpurhr_
gd.pdf, (hereinafter referred to as our ‘‘2003
Tracking Progress Guidance’’).
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5035
natural visibility conditions. In setting
RPGs, states must provide for an
improvement in visibility for the most
impaired days over the (approximately)
10-year period of the SIP, and ensure no
degradation in visibility for the least
impaired days over the same period. Id.
In establishing RPGs, states are
required to consider the following
factors established in section 169A of
the CAA and in our RHR at 40 CFR
51.308(d)(1)(i)(A): (1) The costs of
compliance; (2) the time necessary for
compliance; (3) the energy and non-air
quality environmental impacts of
compliance; and (4) the remaining
useful life of any potentially affected
sources. States must demonstrate in
their SIPs how these factors are
considered when selecting the RPGs for
the best and worst days for each
applicable Class I area. In setting the
RPGs, states must also consider the rate
of progress needed to reach natural
visibility conditions by 2064 (referred to
as the ‘‘uniform rate of progress’’ (URP)
or the ‘‘glidepath’’) and the emission
reduction measures needed to achieve
that rate of progress over the 10-year
period of the SIP. Uniform progress
towards achievement of natural
conditions by the year 2064 represents
a rate of progress, which states are to
use for analytical comparison to the
amount of progress they expect to
achieve. In setting RPGs, each state with
one or more Class I areas (‘‘Class I
state’’) must also consult with
potentially ‘‘contributing states,’’ i.e.,
other nearby states with emission
sources that may be affecting visibility
impairment at the state’s Class I areas.
40 CFR 51.308(d)(1)(iv). In determining
whether a state’s goals for visibility
improvement provide for reasonable
progress toward natural visibility
conditions, EPA is required to evaluate
the demonstrations developed by the
state pursuant to paragraphs 40 CFR
51.308(d)(1)(i) and (d)(1)(ii). 40 CFR
51.308(d)(1)(iii).
iv. Best Available Retrofit Technology
Section 169A of the CAA directs
states to evaluate the use of retrofit
controls at certain larger, often
uncontrolled, older stationary sources in
order to address visibility impacts from
these sources. Specifically, section
169A(b)(2)(A) of the CAA requires states
to revise their SIPs to contain such
measures as may be necessary to make
reasonable progress towards the natural
visibility goal, including a requirement
that certain categories of existing major
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stationary sources10 built between 1962
and 1977 procure, install, and operate
the ‘‘Best Available Retrofit
Technology’’ as determined by the state.
Under the RHR, states are directed to
conduct BART determinations for such
‘‘BART-eligible’’ sources that may be
anticipated to cause or contribute to any
visibility impairment in a Class I area.
Rather than requiring source-specific
BART controls, states also have the
flexibility to adopt an emissions trading
program or other alternative program as
long as the alternative provides greater
reasonable progress towards improving
visibility than BART.
On July 6, 2005, EPA published the
Guidelines for BART Determinations
Under the Regional Haze Rule at
appendix Y to 40 CFR part 51
(hereinafter referred to as the ‘‘BART
Guidelines’’) to assist states in
determining which of their sources
should be subject to the BART
requirements and in determining
appropriate emission limits for each
applicable source. 70 FR 39104. In
making a BART determination for a
fossil fuel-fired electric generating plant
with a total generating capacity in
excess of 750 megawatts (MW), a state
must use the approach set forth in the
BART Guidelines. Generally, a state is
encouraged, but not required, to follow
the BART Guidelines in making BART
determinations for other types of
sources. Regardless of source size or
type, a state must meet the requirements
of the CAA and our regulations for
selection of BART, and the state’s BART
analysis and determination must be
reasonable in light of the overarching
purpose of the regional haze program.
The process of establishing BART
emission limitations can be logically
broken down into three steps: First,
states identify those sources which meet
the definition of ‘‘BART-eligible source’’
set forth in 40 CFR 51.301; 11 second,
states determine which of such sources
‘‘emits any air pollutant which may
reasonably be anticipated to cause or
contribute to any impairment of
visibility in any such area’’ (a source
which fits this description is ‘‘subject to
BART’’); and third, for each source
subject-to-BART, states then identify the
best available type and level of control
for reducing emissions.
10 The set of ‘‘major stationary sources’’
potentially subject-to-BART is listed in CAA section
169A(g)(7).
11 BART-eligible sources are those sources that
have the potential to emit 250 tons or more of a
visibility-impairing air pollutant, were not in
operation prior to August 7, 1962, but were in
existence on August 7, 1977, and whose operations
fall within one or more of 26 specifically listed
source categories. 40 CFR 51.301.
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States must address all visibilityimpairing pollutants emitted by a source
in the BART determination process. The
most significant visibility impairing
pollutants are SO2, NOX, and PM. EPA
has stated that states should use their
best judgment in determining whether
VOC or NH3 emissions impair visibility
in Class I areas.
Under the BART Guidelines, states
may select an exemption threshold
value for their BART modeling, below
which a BART-eligible source would
not be expected to cause or contribute
to visibility impairment in any Class I
area. The state must document this
exemption threshold value in the SIP
and must state the basis for its selection
of that value. Any source with
emissions that model above the
threshold value would be subject to a
BART determination review. The BART
Guidelines acknowledge varying
circumstances affecting different Class I
areas. States should consider the
number of emission sources affecting
the Class I areas at issue and the
magnitude of the individual sources’
impacts. Any exemption threshold set
by the state should not be higher than
0.5 deciview. 40 CFR part 51, appendix
Y, section III.A.1.
In their SIPs, states must identify the
sources that are subject-to-BART and
document their BART control
determination analyses for such sources.
In making their BART determinations,
section 169A(g)(2) of the CAA requires
that states consider the following factors
when evaluating potential control
technologies: (1) The costs of
compliance; (2) the energy and non-air
quality environmental impacts of
compliance; (3) any existing pollution
control technology in use at the source;
(4) the remaining useful life of the
source; and (5) the degree of
improvement in visibility which may
reasonably be anticipated to result from
the use of such technology.
A regional haze SIP must include
source-specific BART emission limits
and compliance schedules for each
source subject-to-BART. Once a state
has made its BART determination, the
BART controls must be installed and in
operation as expeditiously as
practicable, but no later than five years
after the date of EPA approval of the
regional haze SIP. CAA section 169(g)(4)
and 40 CFR 51.308(e)(1)(iv). In addition
to what is required by the RHR, general
SIP requirements mandate that the SIP
must also include all regulatory
requirements related to monitoring,
recordkeeping, and reporting for the
BART controls on the source. See e.g.
CAA section 110(a). As noted above, the
RHR allows states to implement an
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alternative program in lieu of BART so
long as the alternative program can be
demonstrated to achieve greater
reasonable progress toward the national
visibility goal than would BART.
v. Long-Term Strategy
Consistent with the requirement in
section 169A(b) of the CAA that states
include in their regional haze SIP a 10
to 15-year strategy for making
reasonable progress, section 51.308(d)(3)
of the RHR requires that states include
a LTS in their regional haze SIPs. The
LTS is the compilation of all control
measures a state will use during the
implementation period of the specific
SIP submittal to meet applicable RPGs.
The LTS must include ‘‘enforceable
emissions limitations, compliance
schedules, and other measures as
necessary to achieve the reasonable
progress goals’’ for all Class I areas
within, or affected by emissions from,
the state. 40 CFR 51.308(d)(3).
When a state’s emissions are
reasonably anticipated to cause or
contribute to visibility impairment in a
Class I area located in another state, the
RHR requires the impacted state to
coordinate with the contributing states
in order to develop coordinated
emissions management strategies. 40
CFR 51.308(d)(3)(i). In such cases, the
contributing state must demonstrate that
it has included, in its SIP, all measures
necessary to obtain its share of the
emission reductions needed to meet the
RPGs for the Class I area. Id. at (d)(3)(ii).
The RPOs have provided forums for
significant interstate consultation, but
additional consultations between states
may be required to sufficiently address
interstate visibility issues. This is
especially true where two states belong
to different RPOs.
States should consider all types of
anthropogenic sources of visibility
impairment in developing their longterm strategy, including stationary,
minor, mobile, and area sources. At a
minimum, states must describe how
each of the following seven factors
listed below are taken into account in
developing their LTS: (1) Emission
reductions due to ongoing air pollution
control programs, including measures to
address RAVI; (2) measures to mitigate
the impacts of construction activities;
(3) emissions limitations and schedules
for compliance to achieve the RPG; (4)
source retirement and replacement
schedules; (5) smoke management
techniques for agricultural and forestry
management purposes including plans
as currently exist within the state for
these purposes; (6) enforceability of
emissions limitations and control
measures; and (7) the anticipated net
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effect on visibility due to projected
changes in point, area, and mobile
source emissions over the period
addressed by the LTS. 40 CFR
51.308(d)(3)(v).
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vi. Coordinating Regional Haze and
Reasonably Attributable Visibility
Impairment
As part of the RHR, EPA revised 40
CFR 51.306(c) regarding the LTS for
RAVI to require that the RAVI plan must
provide for a periodic review and SIP
revision not less frequently than every
three years until the date of submission
of the state’s first plan addressing
regional haze visibility impairment,
which was due December 17, 2007, in
accordance with 40 CFR 51.308(b) and
(c). On or before this date, the state must
revise its plan to provide for review and
revision of a coordinated LTS for
addressing RAVI and regional haze, and
the state must submit the first such
coordinated LTS with its first regional
haze SIP. Future coordinated LTS’s, and
periodic progress reports evaluating
progress towards RPGs, must be
submitted consistent with the schedule
for SIP submission and periodic
progress reports set forth in 40 CFR
51.308(f) and 51.308(g), respectively.
The periodic review of a state’s LTS
must report on both regional haze and
RAVI impairment and must be
submitted to EPA as a SIP revision.
vii. Monitoring Strategy and Other
Implementation Plan Requirements
Section 51.308(d)(4) of the RHR
includes the requirement for a
monitoring strategy for measuring,
characterizing, and reporting of regional
haze visibility impairment that is
representative of all mandatory Class I
Federal areas within the state. The
strategy must be coordinated with the
monitoring strategy required in section
51.305 for RAVI. Compliance with this
requirement may be met through
‘‘participation’’ in the IMPROVE
network, i.e., review and use of
monitoring data from the network. The
monitoring strategy is due with the first
regional haze SIP, and it must be
reviewed every five years. The
monitoring strategy must also provide
for additional monitoring sites if the
IMPROVE network is not sufficient to
determine whether RPGs will be met.
The SIP must also provide for the
following:
• Procedures for using monitoring
data and other information in a state
with mandatory Class I areas to
determine the contribution of emissions
from within the state to regional haze
visibility impairment at Class I areas
both within and outside the state;
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• Procedures for using monitoring
data and other information in a state
with no mandatory Class I areas to
determine the contribution of emissions
from within the state to regional haze
visibility impairment at Class I areas in
other states;
• Reporting of all visibility
monitoring data to the Administrator at
least annually for each Class I area in
the state, and where possible, in
electronic format;
• Developing a statewide inventory of
emissions of pollutants that are
reasonably anticipated to cause or
contribute to visibility impairment in
any Class I area. The inventory must
include emissions for a baseline year,
emissions for the most recent year for
which data are available, and estimates
of future projected emissions. A state
must also make a commitment to update
the inventory periodically; and
• Other elements, including
reporting, recordkeeping, and other
measures necessary to assess and report
on visibility.
The RHR requires control strategies to
cover an initial implementation period
extending to the year 2018, with a
comprehensive reassessment and
revision of those strategies, as
appropriate, every 10 years thereafter.
Periodic SIP revisions must meet the
core requirements of section 51.308(d)
with the exception of BART. The
requirement to evaluate sources for
BART applies only to the first regional
haze SIP. Facilities subject-to-BART
must continue to comply with the BART
provisions of section 51.308(e), as noted
above. Periodic SIP revisions will assure
that the statutory requirement of
reasonable progress will continue to be
met.
viii. Consultation With States and
Federal Land Managers (FLMs)
The RHR requires that states consult
with FLMs before adopting and
submitting their SIPs. 40 CFR 51.308(i).
States must provide FLMs an
opportunity for consultation, in person
and at least 60 days prior to holding any
public hearing on the SIP. This
consultation must include the
opportunity for the FLMs to discuss
their assessment of impairment of
visibility in any Class I area and to offer
recommendations on the development
of the RPGs and on the development
and implementation of strategies to
address visibility impairment. Further, a
state must include in its SIP a
description of how it addressed any
comments provided by the FLMs.
Finally, a SIP must provide procedures
for continuing consultation between the
state and FLMs regarding the state’s
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5037
visibility protection program, including
development and review of SIP
revisions, five-year progress reports, and
the implementation of other programs
having the potential to contribute to
impairment of visibility in Class I areas.
C. Our Proposal
We signed our notice of proposed
rulemaking on May 23, 2013,12 and it
was published in the Federal Register
on June 10, 2013 (78 FR 34738). In our
2013 proposal, we proposed to approve
many of Wyoming’s regional haze SIP,
including the State’s identification of its
BART sources, its identification of those
BART sources that may be anticipated
to cause or contribute to visibility
impairment, and the State’s BART
determinations for PM. Because of
deficiencies in Wyoming’s NOX BART
analyses, however, we proposed to
disapprove the NOX BART emissions
limitations for a number of sources, as
well as the reasonable progress goals
and long-term strategy. We proposed to
address the NOX BART requirements for
these sources and the other deficiencies
in the Wyoming plan in a FIP, based on
our analysis of the relevant factors. For
several BART sources we also asked in
the proposed rulemaking if interested
parties had additional information
regarding the BART factors and EPA’s
proposed determinations, for example
our weighing of average costs,
incremental costs, visibility
improvement, and timing of installation
of such controls, and in light of such
information, whether the interested
parties thought the Agency should
consider another BART control
technology option that could be
finalized either instead of, or in
conjunction with, BART as proposed.13
In our 2013 proposal we proposed to
disapprove the following:
12 On May 15, 2012 the EPA signed the first
proposed rule on the Wyoming Regional Haze SIP
which proposed to partially approve and partially
disapprove the Wyoming state plan. The EPA
published the proposed rule in the Federal Register
for public comment on June 4, 2012. This public
Federal Register notice may be found at 77 FR
33022 (June 4, 2012). EPA then obtained an
extension to the Consent Decree deadline in order
to re-propose the Wyoming regional haze plan
based on data generated after the conclusion of the
original comment period. In this document, all
references to ‘‘proposal’’ or ‘‘proposal notice’’ refer
to the notice published on June 10, 2013 unless
otherwise stated.
13 E.g., 78 FR 34777. The proposed notice also
explained that ‘‘[t]he Agency will take the
comments and testimony received, as well as any
further SIP revisions submitted by the State, into
consideration in our final promulgation.
Supplemental information received may lead the
Agency to adopt final SIP and/or FIP regulations
that reflect a different BART control technology
option, or impact other proposed regulatory
provisions, which differ from this proposal.’’ 78 FR
34777.
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• The State’s nitrogen oxides (NOX)
best available retrofit technology
(BART) determinations for PacifiCorp
Dave Johnston Units 3 and 4, PacifiCorp
Naughton Units 1 and 2, PacifiCorp
Wyodak Unit 1, and Basin Electric
Laramie River Units 1, 2, and 3.
• The State’s NOX reasonable
progress determinations for PacifiCorp
Dave Johnston Units 1 and 2.
• Wyoming’s reasonable progress
goals (RPGs).
• The State’s monitoring,
recordkeeping, and reporting
requirements in Chapter 6.4 of the SIP.
• Portions of the State’s long-term
strategy (LTS) that rely on or reflect
other aspects of the regional haze SIP
that we are disapproving.
• The provisions necessary to meet
the requirements for the coordination of
the review of the reasonably attributable
visibility impairment (RAVI) and the
regional haze LTS.
We proposed the promulgation of a
FIP to address the deficiencies in the
Wyoming regional haze SIP that we
identified in the proposed notice. The
proposed FIP included the following
elements:
• NOX BART determinations and
limits for PacifiCorp Dave Johnston
Units 3 and 4, PacifiCorp Naughton
Units 1 and 2, PacifiCorp Wyodak Unit
1, and Basin Electric Laramie River
Units 1, 2, and 3.
• NOX reasonable progress
determinations and limits for PacifiCorp
Dave Johnston Units 1 and 2.
• RPGs consistent with the SIP limits
proposed for approval and the proposed
FIP limits.
• Monitoring, recordkeeping, and
reporting requirements applicable to all
BART and reasonable progress sources
for which there is a SIP or FIP emissions
limit.
• LTS elements pertaining to
emission limits and compliance
schedules for the proposed BART and
reasonable progress FIP emission limits.
• Provisions to ensure the
coordination of the RAVI and regional
haze LTS.
We also requested comment on an
alternative proposal, related to the
State’s NOX BART determinations, for
PacifiCorp Jim Bridger Units 1 and 2,
that would involve disapproval and the
promulgation of a FIP.
D. Public Participation
We requested comments on all
aspects of our proposed action. In our
proposed rulemaking, we provided a 60day comment period, with the comment
period closing on August 9, 2013. We
also held a public hearing on June 24,
2013, in Cheyenne, Wyoming. We
received requests from Wyoming’s
governor, congressional delegation, and
Department of Environmental Quality
(DEQ), among others, for additional
public hearings and an extended public
comment period. As a result, we held
two more public hearings. We held a
hearing on July 17, 2013, in Cheyenne,
Wyoming, and on July 26, 2013, in
Casper, Wyoming. We also extended the
comment period to August 26, 2013. We
provided public notice of the additional
hearings and extension of the public
comment period on July 8, 2013. 78 FR
40654.
II. Final Action
Based upon comments received on
our proposed action, in this final action
we are partially approving and partially
disapproving Wyoming’s regional haze
SIP submitted on January 12, 2011. We
are approving the majority of the State’s
regional haze determinations. For the
fifteen coal fired power plant units in
Wyoming subject to the regional haze
requirements, we are approving the
State’s NOX emission control technology
decisions for 10 of those units. We are
also approving the State’s plan for the
non-power plant facilities subject to
regional haze requirements and the
State’s plan for control of PM. We are
approving all aspects of Wyoming’s SIP,
except for the following elements which
we are disapproving:
• The State’s NOX BART
determinations for PacifiCorp Dave
Johnston Unit 3, PacifiCorp Wyodak
Unit 1, and Basin Electric Laramie River
Units 1, 2, and 3.
• Wyoming’s RPGs.
• The State’s monitoring,
recordkeeping, and reporting
requirements in Chapter 6.4 of the SIP.
• Portions of the State’s LTS that rely
on or reflect other aspects of the
regional haze SIP that we are
disapproving.
• The provisions necessary to meet
the requirements for the coordination of
the review of the RAVI and the regional
haze LTS.
The final FIP includes the following
elements:
• NOX BART determinations and
emission limits for PacifiCorp Dave
Johnston Unit 3, Wyodak Unit 1, and
Basin Electric Laramie River Units 1, 2,
and 3.
• RPGs consistent with the SIP
emission limits finalized for approval
and the finalized FIP emission limits.
• Monitoring, recordkeeping, and
reporting requirements applicable to all
BART sources for which there is a SIP
or FIP emissions limit.
• LTS elements pertaining to
emission limits and compliance
schedules for the finalized FIP emission
limits.
• Provisions to ensure the
coordination of the RAVI and regional
haze LTS.
Although we are promulgating a
Federal plan, a state may always submit
a new regional haze SIP to EPA for
review and we would welcome such a
submission. The CAA requires EPA to
take action on such a SIP submittal that
is determined to be complete within 12
months. If the State were to submit a
revision meeting the requirements of the
CAA and the regional haze regulations,
we would propose approval of the
State’s plan as expeditiously as
practicable. We are mindful of the costs
of our final action but have considered
the costs and visibility improvement
that other states and EPA have required
for BART controls.
Table 1 shows the NOX BART control
technologies, associated cost, and
emission reductions for each source that
is subject to the FIP.
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TABLE 1—CONTROL TECHNOLOGIES, COSTS, EMISSION LIMITS, AND COST EFFECTIVENESS FOR SOURCES SUBJECT TO
THE FIP
Source
Dave Johnston
Unit 3.
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Emission
limit—lb/MMBtu
(30-day rolling
average)
Technology *
New low-NOX burners (LNBs) with
overfire air (OFA) and shut down in
2027; or new LNBs with OFA and
selective
catalytic
reduction
(SCR) **.
21:27 Jan 29, 2014
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with OFA).
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Total capital cost
($)
Total annualized
cost
($)
$15,976,696 (for
LNBs with OFA).
$1,828,137 (for
LNBs with OFA).
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Average costeffectiveness
($/ton)
$644 (for LNBs
with OFA).
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TABLE 1—CONTROL TECHNOLOGIES, COSTS, EMISSION LIMITS, AND COST EFFECTIVENESS FOR SOURCES SUBJECT TO
THE FIP—Continued
Technology *
Emission
limit—lb/MMBtu
(30-day rolling
average)
Total capital cost
($)
Total annualized
cost
($)
River Unit
New LNBs/OFA and SCR ..................
0.07 ......................
$180,254,572 .......
$21,770,134 .........
$4,461.
River Unit
New LNBs with OFA and SCR ..........
0.07 ......................
$188,826,333 .......
$22,691,467 .........
$4,424.
River Unit
New LNBs with OFA and SCR ..........
0.07 ......................
$188,437,953 .......
$22,666,982 .........
$4,375.
Unit 1 ......
New LNBs with OFA and SCR ..........
0.07 ......................
$119,501,862 .......
$12,714,153 .........
$4,036.
Source
Laramie
1.
Laramie
2.
Laramie
3.
Wyodak
Average costeffectiveness
($/ton)
* The
technology listed is the technology evaluated as BART, but sources can choose to use another technology or combination of technologies to meet established limits.
** As used in this and the following tables, ‘‘new’’ means replacing the control technology that was in place at the time of the State’s BART
analyses in May 2009 with new control technology, most of which was installed post-2009.
III. Changes From Proposed Rule and
Reasons for Changes
A. Changes to Proposed Costs and
Visibility Improvements
As described in this section and
elsewhere in today’s final rule, we have
revised our cost of compliance analysis
and visibility improvement modeling
from our June 10, 2013 proposed action
for all of the BART and reasonable
progress electric generating units
(EGUs).
EPA revised the cost analyses from
those found in the proposed rule based
upon input from various commenters.
Some of factors that caused us to revise
our cost estimates included accounting
for site elevation in the SCR capital cost,
change in SCR reagent to anhydrous
ammonia from urea, change in auxiliary
electrical cost from market price to
generating cost, change in urea SNCR
chemical utilization for some units due
to high furnace temperatures, and
consideration of shorter plant lifetimes
in some instances. In addition, EPA
incorporated some of the costs provided
by commenters in their site specific cost
estimates where we found those costs to
be sufficiently supported. Per EPA’s
Control Cost Manual (CCM), use of site
specific cost estimates is preferable to
the use of generalized costs where those
site specific costs can be supported and
are appropriate.
EPA addressed comments on the
visibility improvement modeling in the
proposed rule by developing a new
protocol that makes several
improvements in the modeling,
including the use of the current
regulatory version of the CALPUFF
model (version 5.8), the use of an
improved method to assess the effects of
pollutants on light scattering and
visibility impairment (Method 8), the
use of lower background ammonia
concentrations, and the use of an
ammonia limiting correction for BART
sources with multiple units. In
particular, we have used new values for
ammonia background that reflect robust
monitoring data and the appropriate
default concentrations for the geography
in the state.
The results of our revised cost
analysis, along with the revised
visibility impacts, are presented in
Tables 2 through 17 below and
summarized for each source below the
set of tables for that source. Details
regarding our revised cost analysis and
visibility improvement modeling can be
found in the docket.14 15
TABLE 2—SUMMARY OF EPA’S LARAMIE RIVER UNIT 1 NOX BART ANALYSIS
Emission rate
(lb/MMBtu;
annual
average)
Control technology
mstockstill on DSK4VPTVN1PROD with RULES2
New LNBs with OFA .................................................................
New LNBs with OFA and selective non-catalytic reduction
(SNCR) ..................................................................................
New LNBs with OFA and SCR .................................................
14 Andover Technology Partners, ‘‘Cost of NO
X
Controls on Wyoming EGUs’’, October 28, 2013;
Wyoming EGU BART and Reasonable Progress
VerDate Mar<15>2010
18:38 Jan 29, 2014
Jkt 232001
Emission
reduction
(tpy)
Frm 00009
Incremental
cost
effectiveness
($/ton)
0.19
1,556
$2,268,806
$1,458
........................
0.18
0.15
0.05
2,445
4,880
8,554,896
21,770,134
3,485
4,461
$6,993
5,449
0.28
0.57
Costs—10/28/2013; Wyoming EGU BART and
Reasonable Progress Costs for Jim Bridger—10/28/
2013.
PO 00000
Average cost
effectiveness
($/ton)
Annualized
costs
Visibility
improvement
(Delta
deciview for
the maximum
98th percentile
impact at
Badlands
National Park)
Fmt 4701
Sfmt 4700
15 Air Quality Modeling Protocol: Wyoming
Regional Haze Federal Implementation Plan, U.S.
EPA, January, 2014.
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Federal Register / Vol. 79, No. 20 / Thursday, January 30, 2014 / Rules and Regulations
TABLE 3—SUMMARY OF EPA’S LARAMIE RIVER UNIT 2 NOX BART ANALYSIS
Emission rate
(lb/MMBtu;
annual
average)
Control technology
New LNBs with OFA .................................................................
New LNBs with OFA and SNCR ..............................................
New LNBs with OFA and SCR .................................................
0.19
0.15
0.05
Emission
reduction
(tpy)
1823
2,717
5,129
Incremental
cost
effectiveness
($/ton)
Average cost
effectiveness
($/ton)
Annualized
costs
$2,268,806
8,531,631
22,691,467
$1,244
3,140
4,424
........................
$7,006
5,871
Visibility
improvement
(Delta
deciview for
the maximum
98th percentile
impact at
Badlands
National Park)
0.18
0.27
0.53
TABLE 4—SUMMARY OF EPA’S LARAMIE RIVER UNIT 3 NOX BART ANALYSIS
Emission rate
(lb/MMBtu;
annual
average)
Control technology
New LNBs with OFA .................................................................
New LNBs with OFA and SNCR ..............................................
New LNBs with OFA and SCR .................................................
EPA’s January 2014 modeling
protocol, Appendix H, shows the model
predicted visibility improvement for
each emissions control technology at
each of the Class I areas that we
modeled in our analysis. For Laramie
River we modeled visibility impairment
at Badlands National Park, Wind Cave
National Park, Rawah Wilderness Area,
and Rocky Mountain National Park. At
0.19
0.15
0.05
Emission
reduction
(tpy)
1789
2,706
5,181
$2,268,806
8,643,839
22,666,982
Laramie River Unit 1 the model
visibility improvements with LNB/OFA/
SCR were 0.57 deciviews at Badlands
National Park, 0.47 deciviews at Wind
Cave National Park, 0.25 deciviews at
Rawah Wilderness Area, and 0.39 at
Rocky Mountain National Park. At
Laramie River Unit 2 the model
visibility improvements with LNB/OFA/
SCR were 0.53 deciviews at Badlands,
Incremental
cost
effectiveness
($/ton)
Average cost
effectiveness
($/ton)
Annualized
costs
$1,268
3,194
4,375
........................
$6,951
5,667
Visibility
improvement
(Delta
deciview for
the maximum
98th percentile
impact at
Badlands
National Park)
0.18
0.27
0.52
0.43 deciviews at Wind Cave, 0.26
deciviews at Rawah, and 0.31 at Rocky
Mountain. At Laramie River Unit 3 the
model visibility improvements with
LNB/OFA/SCR were 0.52 deciviews at
Badlands, 0.44 deciviews at Wind Cave,
0.23 deciviews at Rawah, and 0.28 at
Rocky Mountain.
TABLE 5—SUMMARY OF EPA’S JIM BRIDGER UNIT 1 NOX BART ANALYSIS
Emission rate
(lb/MMBtu;
annual
average)
Control technology
New LNBs with SOFA ...............................................................
New LNBs with SOFA and SNCR ............................................
New LNBs with SOFA and SCR ...............................................
0.18
0.14
0.05
Emission
reduction
(tpy)
Annualized
costs
4,558
5,332
7,352
Incremental
cost
effectiveness
($/ton)
Average cost
effectiveness
($/ton)
$1,167,297
4,330,052
19,372,105
$256
812
2,635
........................
$4,088
7,447
Visibility
improvement
(Delta
deciview for
the maximum
98th percentile
impact at
Bridger
Wilderness
Area) **
0.17/0.23
0.20/0.27
0.27/0.37
* Values shown are model results using ammonia based on monitoring and default data; values in straight font are model results using a monitored monthly varying
concentration/values in italics are model results using an IWAQM default 0.5 ppb background ammonia.
TABLE 6—SUMMARY OF EPA’S JIM BRIDGER UNIT 2 NOX BART ANALYSIS
Emission rate
(lb/MMBtu;
annual
average)
mstockstill on DSK4VPTVN1PROD with RULES2
Control technology
New LNBs with SOFA ...............................................................
New LNBs with SOFA and SNCR ............................................
New LNBs with SOFA and SCR ...............................................
0.19
0.15
0.05
Emission
reduction
(tpy)
Annualized
costs
3,787
4,545
6,554
Average cost
effectiveness
($/ton)
$1,167,297
4,291,184
22,307,492
$308
944
3,403
Incremental
cost
effectiveness
($/ton)
........................
$4,122
8,968
Visibility
improvement
(Delta
deciview for
the maximum
98th percentile
impact at
Bridger
Wilderness
Area) *
0.16/0.21
0.19/0.25
0.27/0.36
* Values shown are model results using ammonia based on monitoring and default data; values in straight font are model results using a monitored monthly varying
concentration/values in italics are model results using an IWAQM default 0.5 ppb background ammonia.
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5041
TABLE 7—SUMMARY OF EPA’S JIM BRIDGER UNIT 3 NOX BART ANALYSIS
Emission rate
(lb/MMBtu;
annual
average)
Control technology
New LNBs with SOFA ...............................................................
New LNBs with SOFA and SNCR ............................................
New LNBs with SOFA and SCR ...............................................
0.20
0.16
0.05
Emission
reduction
(tpy)
3,710
4,539
6,799
Incremental
cost
effectiveness
($/ton)
Average cost
effectiveness
($/ton)
Annualized
costs
$1,167,297
4,458,776
22,573,920
$315
982
3,320
........................
$3,972
8,015
Visibility
improvement
(Delta
deciview for
the maximum
98th percentile
impact at
Bridger
Wilderness
Area) *
0.14/0.19
0.17/0.23
0.26/0.35
* Values shown are model results using ammonia based on monitoring and default data; values in straight font are model results using a monitored monthly varying
concentration/values in italics are model results using an IWAQM default 0.5 ppb background ammonia.
TABLE 8—SUMMARY OF EPA’S JIM BRIDGER UNIT 4 NOX BART ANALYSIS
Emission rate
(lb/MMBtu;
annual
average)
Control technology
New LNBs with SOFA ...............................................................
New LNBs with SOFA and SNCR ............................................
New LNBs with SOFA and SCR ...............................................
0.19
0.15
0.05
Emission
reduction
(tpy)
Average cost
effectiveness
($/ton)
Annualized
costs
4,161
4,956
7,108
$1,167,297
4,372,457
19,494,417
$281
882
2,743
Incremental
cost
effectiveness
($/ton)
........................
$4,035
7,027
Visibility
improvement
(Delta
deciview for
the maximum
98th percentile
impact at
Rawah
Wilderness
Area) *
0.25/0.23
0.30/0.28
0.45/0.42
mstockstill on DSK4VPTVN1PROD with RULES2
* Values shown are model results using ammonia based on monitoring and default data; values in straight font are model results using a monitored monthly varying
concentration/values in italics are model results using an IWAQM default 0.5 ppb background ammonia.
EPA’s January 2014 modeling
protocol, Appendix H, shows the model
predicted visibility improvement for
each emissions control technology at
each of the Class I areas that we
modeled in our analysis of Jim Bridger.
Model simulations were performed
using a monthly varying background
ammonia concentration and using the
IWAQM default concentration for
forested areas of 0.5 ppb. For Jim
Bridger we modeled visibility
impairment at Bridger Wilderness Area,
Fitzpatrick Wilderness Area, Mt Zirkel
Wilderness Area, Rawah Wilderness
Area, Rocky Mountain National Park,
Grand Teton National Park, Teton
Wilderness Area, Washakie Wilderness
Area and Yellowstone National Park.
Under the State’s LTS, LNB/OFA/SCR
would be required on Jim Bridger Units
1 and 2 in 2022 and 2021. Under the
State’s LTS, LNB/OFA/SCR would be
required on Jim Bridger Units 3 and 4
in 2015 and 2016.
For Jim Bridger Unit 1, using monthly
varying ammonia concentrations, model
visibility improvements with LNB/OFA/
SCR were: 0.37 deciviews at Bridger;
0.26 deciviews at Fitzpatrick; 0.29
deciviews at Mt Zirkel; 0.35deciviews at
Rawah; 0.36 deciviews at Rocky
Mountain; 0.17 deciviews at Grand
Teton; 0.14 deciviews at Teton; 0.19
deciviews at Washakie; and 0.15
deciviews at Yellowstone.
VerDate Mar<15>2010
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For Jim Bridger Unit 1, using a
constant 0.5 ppb ammonia
concentration, model visibility
improvements with LNB/OFA/SCR
were: 0.37 deciviews at Bridger; 0.26
deciviews at Fitzpatrick; 0.29 deciviews
at Mt Zirkel; 0.35 deciviews at Rawah;
0.36 deciviews at Rocky Mountain; 0.17
deciviews at Grand Teton; 0.14
deciviews at Teton; 0.19 deciviews at
Washakie; and 0.15 deciviews at
Yellowstone.
For Jim Bridger Unit 2, using monthly
varying ammonia concentrations, model
visibility improvements with LNB/OFA/
SCR were: 0.36 deciviews at Bridger;
0.26 deciviews at Fitzpatrick; 0.28
deciviews at Mt Zirkel; 0.35 deciviews
at Rawah; 0.36 deciviews at Rocky
Mountain; 0.16 deciviews at Grand
Teton; 0.14 deciviews at Teton; 0.19
deciviews at Washakie; and 0.14
deciviews at Yellowstone.
For Jim Bridger Unit 2, using a
constant 0.5 ppb ammonia
concentration, model visibility
improvements with LNB/OFA/SCR
were: 0.36 deciviews at Bridger; 0.26
deciviews at Fitzpatrick; 0.28 deciviews
at Mt Zirkel; 0.35 deciviews at Rawah;
0.36 deciviews at Rocky Mountain; 0.16
deciviews at Grand Teton; 0.14
deciviews at Teton; 0.19 deciviews at
Washakie; and 0.14 deciviews at
Yellowstone.
For Jim Bridger Unit 3, using monthly
varying ammonia concentrations, model
PO 00000
Frm 00011
Fmt 4701
Sfmt 4700
visibility improvements with LNB/OFA/
SCR were: 0.35 deciviews at Bridger;
0.25 deciviews at Fitzpatrick; 0.28
deciviews at Mt Zirkel; 0.33 deciviews
at Rawah; 0.34 deciviews at Rocky
Mountain; 0.16 deciviews at Grand
Teton; 0.14 deciviews at Teton; 0.18
deciviews at Washakie; and 0.14
deciviews at Yellowstone.
For Jim Bridger Unit 3, using a
constant 0.5 ppb ammonia
concentration, model visibility
improvements with LNB/OFA/SCR
were: 0.35 deciviews at Bridger; 0.25
deciviews at Fitzpatrick; 0.28 deciviews
at Mt Zirkel; 0.33 deciviews at Rawah;
0.34 deciviews at Rocky Mountain; 0.16
deciviews at Grand Teton; 0.14
deciviews at Teton; 0.18 deciviews at
Washakie; and 0.14 deciviews at
Yellowstone.
For Jim Bridger Unit 4, using monthly
varying ammonia concentrations, model
visibility improvements with LNB/OFA/
SCR were: 0.38 deciviews at Bridger;
0.28 deciviews at Fitzpatrick; 0.19
deciviews at Mt Zirkel; 0.42 deciviews
at Rawah; 0.38 deciviews at Rocky
Mountain; 0.32 deciviews at Grand
Teton; 0.15 deciviews at Teton; 0.30
deciviews at Washakie; and 0.16
deciviews at Yellowstone.
For Jim Bridger Unit 4, using a
constant 0.5 ppb ammonia
concentration, model visibility
improvements with LNB/OFA/SCR
were: 0.38 deciviews at Bridger; 0.28
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deciviews at Fitzpatrick; 0.27 deciviews
at Mt Zirkel; 0.42 deciviews at Rawah;
0.38 deciviews at Rocky Mountain; 0.32
deciviews at Grand Teton; 0.15
deciviews at Teton; 0.30 deciviews at
Washakie; and 0.16 deciviews at
Yellowstone.
TABLE 9—SUMMARY OF EPA’S DAVE JOHNSTON UNIT 3 NOX BART ANALYSIS
[9 Year remaining useful life]
Emission rate
(lb/MMBtu;
annual
average)
Control technology
New LNBs with OFA ................................
New LNBs with OFA and SNCR .............
New LNBs with OFA and SCR ................
0.22
0.16
0.05
Emission
reduction
(tpy)
Annualized
costs
2,837
3,356
4,433
Average cost
effectiveness
($/ton)
$1,828,137
3,898,930
16,591,006
$644
1,162
3,742
Incremental
cost
effectiveness
($/ton)
........................
$3,988
11,781
Visibility improvement
(Delta
deciview for
the maximum
98th percentile
impact at Wind
Cave National
Park)
0.33
0.39
0.51
TABLE 10—SUMMARY OF EPA’S DAVE JOHNSTON UNIT 3 NOX BART ANALYSIS
[20 Year remaining useful life]
Emission rate
(lb/MMBtu;
annual
average)
Control technology
New LNBs with OFA ................................
New LNBs with OFA and SNCR .............
New LNBs with OFA and SCR ................
0.22
0.16
0.05
Emission
reduction
(tpy)
Annualized
costs
2,837
3,356
4,433
Average cost
effectiveness
($/ton)
$1,699,807
3,510,589
11,680,144
$599
1,046
2,635
Incremental
cost
effectiveness
($/ton)
........................
$3,488
7,583
Visibility improvement
(Delta
deciview for
the maximum
98th percentile
impact at Wind
Cave National
Park)
0.33
0.39
0.51
TABLE 11—SUMMARY OF EPA’S DAVE JOHNSTON UNIT 4 NOX BART ANALYSIS
Emission rate
(lb/MMBtu;
annual
average)
Control technology
New LNBs with OFA ................................
New LNBs with OFA and SNCR .............
New LNBs with OFA and SCR ................
0.14
0.11
0.05
mstockstill on DSK4VPTVN1PROD with RULES2
EPA’s January 2014 modeling
protocol, Appendix H, shows the model
predicted visibility improvement for
each emissions control technology at
each of the Class I areas that we
modeled in our analysis of Dave
Johnston. For Dave Johnston we
modeled visibility impairment at
Badlands National Park, Wind Cave
National Park, Mt Zirkel Wilderness
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Jkt 232001
Emission
reduction
(tpy)
Annualized
costs
3,114
3,505
4,377
$767,342
2,541,600
14,158,899
Area, Rawah Wilderness Area, and
Rocky Mountain National Park. At Dave
Johnston Unit 3 the model visibility
improvements with LNB/OFA/SCR
were 0.47 deciviews at Badlands
National Park, 0.51 deciviews at Wind
Cave National Park, 0.20 deciviews at
Mt Zirkel Wilderness Area, 0.40
deciviews at Rawah Wilderness Area,
and 0.28 at Rocky Mountain National
PO 00000
Frm 00012
Fmt 4701
Sfmt 4700
Average cost
effectiveness
($/ton)
$246
725
3,235
Incremental
cost
effectiveness
($/ton)
........................
$4,535
13,312
Visibility improvement
(Delta
deciview for
the maximum
98th percentile
impact at Wind
Cave National
Park)
0.41
0.46
0.57
Park. At Dave Johnston Unit 4 the model
visibility improvements with LNB/OFA
were 0.55 deciviews at Badlands
National Park, 0.57 deciviews at Wind
Cave National Park, 0.24 deciviews at
Mt Zirkel Wilderness Area, 0.34
deciviews at Rawah Wilderness Area,
and 0.33 deciviews at Rocky Mountain
National Park.
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5043
TABLE 12—SUMMARY OF EPA’S NAUGHTON UNIT 1 NOX BART ANALYSIS
Emission
rate (lb/
MMBtu;
annual
average)
Control technology
New LNBs with OFA ................................
New LNBs with OFA and SNCR .............
New LNBs with OFA and SCR ................
0.21
0.16
0.05
Emission
reduction
(tpy)
Annualized
costs
2,100
2,463
3,209
Average cost
effectiveness
($/ton)
$932,466
2,234,827
9,974,616
$444
907
3,109
Incremental
cost
effectiveness
($/ton)
........................
$3,584
10,384
Visibility improvement
(Delta
deciview for
the Maximum
98th percentile
impact at
Bridger
Wilderness
Area) *
0.22/0.26
0.26/0.30
0.33/0.39
* Values shown are model results using ammonia based on monitoring and default data; values in straight font are model results using a monitored monthly varying concentration/values in italics are model results using an IWAQM default 0.5 ppb background ammonia.
TABLE 13—SUMMARY OF EPA’S NAUGHTON UNIT 2 NOX BART ANALYSIS
Emission rate
(lb/MMBtu;
annual
average)
Control technology
New LNBs with OFA ................................
New LNBs with OFA and SNCR .............
New LNBs with OFA and SCR ................
0.21
0.16
0.05
Emission
reduction
(tpy)
Annualized
costs
2,586
3,024
3,922
Average cost
effectiveness
($/ton)
$883,900
2,480,832
10,062,750
$342
820
2,566
Incremental
cost
effectiveness
($/ton)
........................
$3,647
8,440
Visibility improvement
(Delta
deciview for
the Maximum
98th percentile
impact at
Bridger
Wilderness
Area) *
0.28/0.32
0.34/0.38
0.42/0.46
* Values shown are model results using ammonia based on monitoring and default data; values in straight font are model results using a monitored monthly varying concentration/values in italics are model results using an IWAQM default 0.5 ppb background ammonia.
TABLE 14—SUMMARY OF EPA’S NAUGHTON UNIT 3 NOX BART ANALYSIS
[In lieu of conversion of Naughton Unit 3 to natural gas per PacifiCorp request]
Emission rate
(lb/MMBtu;
annual
average)
Control technology
Existing LNBs with OFA** ........................
Existing LNBs with OFA and SNCR ........
Existing LNBs with OFA and SCR ..........
0.33
0.23
0.05
Emission
reduction
(tpy)
Annualized
costs
442
1,673
3,922
Average cost
effectiveness
($/ton)
$106,393
3,852,377
13,604,702
$240
2,303
3,469
Incremental
cost
effectiveness
($/ton)
........................
$3,045
4,335
Visibility improvement
(Delta
deciview for
the Maximum
98th percentile
impact at
Bridger
Wilderness
Area) *
0.05/0.07
0.20/0.29
0.49/0.60
mstockstill on DSK4VPTVN1PROD with RULES2
* Values shown are model results using ammonia based on monitoring and default data; values in straight font are model results using a monitored monthly varying concentration/values in italics are model results using an IWAQM default 0.5 ppb background ammonia.
** As used in this table, ‘‘existing’’ means the control technology that was in place at the time of the State’s BART analyses in May 2009.
EPA’s January 2014 modeling
protocol, Appendix H, shows the model
predicted visibility improvement for
each emissions control technology at
each of the Class I areas that we
modeled in our analysis of Naughton.
For Naughton we modeled visibility
impairment at Bridger Wilderness Area,
Fitzpatrick Wilderness Area, North
Absaroka Wilderness Area, Washakie
Wilderness Area, Teton Wilderness
Area, Grand Teton National Park and
Yellowstone National Park. Model
simulations were performed using a
VerDate Mar<15>2010
18:38 Jan 29, 2014
Jkt 232001
monthly varying background ammonia
concentration and using the IWAQM
default concentration for forested areas
of 0.5 ppb.
For Naughton Unit 1 model visibility
improvements, using monthly varying
ammonia concentrations, with LNB/
OFA and LNB/OFA/SCR were,
respectively: 0.22 and 0.33 deciviews at
Bridger; 0.19 and 0.29 deciviews at
Fitzpatrick; 0.10 and 0.14 at North
Absaroka; 0.10 and 0.15 deciviews at
Washakie; 0.10 and 0.16 deciviews at
Teton; 0.15 and 0.23 deciviews at Grand
PO 00000
Frm 00013
Fmt 4701
Sfmt 4700
Teton; and 0.12 and 0.18 deciviews at
Yellowstone.
For Naughton Unit 1 model visibility
improvements, using a constant 0.5 ppb
ammonia concentration, with LNB/OFA
and LNB/OFA/SCR were, respectively:
0.26 and 0.39 deciviews at Bridger; 0.22
and 0.30 deciviews at Fitzpatrick; 0.10
and 0.14 at North Absaroka; 0.12 and
0.17 deciviews at Washakie; 0.13 and
0.19 deciviews at Teton; 0.19 and 0.29
deciviews at Grand Teton; and 0.13 and
0.19 deciviews at Yellowstone.
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For Naughton Unit 2 model visibility
improvements, using monthly varying
ammonia concentrations, with LNB/
OFA and LNB/OFA/SCR were,
respectively: 0.28 and 0.42 deciviews at
Bridger; 0.25 and 0.36 deciviews at
Fitzpatrick; 0.12 and 0.17 at North
Absaroka; 0.15 and 0.22 deciviews at
Washakie; 0.14 and 0.21 deciviews at
Teton; 0.18 and 0.28 deciviews at Grand
Teton; and 0.16 and 0.22 deciviews at
Yellowstone.
For Naughton Unit 2 model visibility
improvements, using a constant 0.5 ppb
ammonia concentration, with LNB/OFA
and LNB/OFA/SCR were, respectively:
0.32 and 0.46 deciviews at Bridger; 0.26
and 0.38 deciviews at Fitzpatrick; 0.12
and 0.17 at North Absaroka; 0.16 and
0.22 deciviews at Washakie; 0.17 and
0.25 deciviews at Teton; 0.25 and 0.38
deciviews at Grand Teton; and 0.17 and
0.24 deciviews at Yellowstone.
For Naughton Unit 3 model visibility
improvements, using monthly varying
ammonia concentrations, with LNB/
OFA and LNB/OFA/SCR were,
respectively: 0.05 and 0.49 deciviews at
Bridger; 0.05 and 0.42 deciviews at
Fitzpatrick; 0.03 and 0.24 at North
Absaroka; 0.05 and 0.37 deciviews at
Washakie; 0.04 and 0.38 deciviews at
Teton; 0.04 and 0.38 deciviews at Grand
Teton; and 0.04 and 0.39 deciviews at
Yellowstone.
For Naughton Unit 3 model visibility
improvements, using a constant 0.5 ppb
ammonia concentration, with LNB/OFA
and LNB/OFA/SCR were, respectively:
0.07 and 0.60 deciviews at Bridger; 0.05
and 0.44 deciviews at Fitzpatrick; 0.03
and 0.24 at North Absaroka; 0. and 0.
deciviews at Washakie; 0.05 and 0.39
deciviews at Teton; 0.06 and 0.41
deciviews at Grand Teton; and 0.05 and
0.40 deciviews at Yellowstone.
TABLE 15—SUMMARY OF EPA’S WYODAK NOX BART ANALYSIS
Emission rate
(lb/MMBtu;
annual
average)
Control technology
New LNBs with OFA .................................................................
New LNBs with OFA and SNCR ..............................................
New LNBs with OFA and SCR .................................................
EPA’s January 2014 modeling
protocol, Appendix H, shows the model
predicted visibility improvement for
each emissions control technology at
each of the Class I areas that we
0.19
0.15
0.05
Emission
reduction
tpy)
Average cost
effectiveness
($/ton)
Annualized
costs
1,239
1,914
3,735
$1,272,427
3,726,573
15,073,502
modeled in our analysis of Wyodak . For
Wyodak we modeled visibility
impairment at Badlands National Park
and Wind Cave National Park. At
Wyodak Unit 1 the model visibility
$1,027
1,947
4,036
Incremental
cost
effectiveness
($/ton)
........................
3,635
6,233
Visibility improvement
(delta
deciview for
the maximum
98th percentile
impact at Wind
Cave National
Park)
0.21
0.32
0.61
improvements with LNB/OFA/SCR
were 0.61 deciviews at Wind Cave and
0.38 deciviews at Badlands National
Park.
TABLE 16—SUMMARY OF EPA’S DAVE JOHNSTON UNIT 1 NOX REASONABLE PROGRESS ANALYSIS
Emission rate
(lb/MMBtu;
annual
average)
Control technology
LNBs with OFA * .......................................................................
LNBs with OFA and SNCR .......................................................
LNBs with OFA and SCR .........................................................
0.20
0.15
0.05
Emission
reduction
(tpy)
Annualized
costs
1,226
1,466
1,947
Average cost
effectiveness
($/ton)
$1,214,000
2,096,430
6,808,374
$990
1,430
3,496
Incremental
cost
effectiveness
($/ton)
........................
3,670
9,798
Visibility improvement
(delta
deciview for
the maximum
98th percentile
impact at Wind
Cave National
Park)
0.12
0.14
0.18
* As used in this and the following tables, control technology that is not preceded by either ‘‘new’’ or ‘‘existing’’ (as in the above tables) means the control technology will be installed for the first time.
TABLE 17—SUMMARY OF EPA’S DAVE JOHNSTON UNIT 2 NOX REASONABLE PROGRESS ANALYSIS
Emission rate
(lb/MMBtu;
annual
average)
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Control technology
LNBs with OFA .........................................................................
LNBs with OFA and SNCR .......................................................
LNBs with OFA and SCR .........................................................
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0.20
0.15
0.05
Fmt 4701
Emission
reduction
(tpy)
Annualized
costs
1,180
1,425
1,916
Sfmt 4700
Average cost
effectiveness
($/ton)
Incremental
cost effectiveness
($/ton)
Visibility improvement
(delta
deciview for
the maximum
98th percentile
impact at Wind
Cave National
Park)
$1,221
1,638
3,673
........................
3,645
9,588
0.11
0.14
0.18
$1,441,146
2,335,022
7,037,969
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B. Changes to Our Proposed
Determinations
1. Dave Johnston Unit 3
We proposed to require PacifiCorp
Dave Johnston Unit 3 to meet a FIP
emission limit of 0.07 lb/MMBtu (30day rolling average) for NOX BART
(assumes the installation of LNBs/OFA
plus SCR). Based on our revised costs of
compliance and visibility impacts, we
would still conclude that NOX BART is
an emission limit of 0.07 lb/MMBtu (30day rolling average). PacifiCorp
submitted comments on our proposed
rulemaking on August 26, 2013. In those
comments, PacifiCorp indicated in
various places (e.g., page 37) that
instead of installing SCR, it would shut
down Dave Johnston Unit 3 in 2027.
Our regulatory language now provides
PacifiCorp two alternative paths to
compliance with the FIP. The first path
includes a requirement for Dave
Johnston Unit 3 to cease operation by
December 31, 2027. For this path, we
are requiring Dave Johnston Unit 3 to
meet a FIP limit of 0.28 lb/MMBtu (30day rolling average) no later than five
years after the date of our final action.
This emission limit assumes the
installation of LNBs/OFA. The second
compliance path gives PacifiCorp the
option to instead meet a 0.07 lb/MMBtu
emission limit (assumes installation of
SCR) within five years of our final
action with no requirement for shut
down.
EPA met with PacifiCorp on October
31, 2013, to clarify the comments
submitted by PacifiCorp (see October
31, 2013 memo to docket). Specifically,
EPA asked if, in lieu of a requirement
for SCR, PacifiCorp was asking for EPA
to include an enforceable requirement
in the FIP for Dave Johnston Unit 3 to
shut down in 2027, and for EPA to make
a BART determination based on that
limited remaining useful life. PacifiCorp
confirmed that it did want EPA to
include an enforceable requirement in
the FIP for PacifiCorp to shut down
Dave Johnston Unit 3 by December 31,
2027, and to make a BART
determination accordingly. As detailed
in the following section, we determined
that if the unit shuts down by December
31, 2027, SCR would no longer be NOX
BART.
Generally, EPA does not interpret the
regional haze rule to provide us with
authority to make a BART
determination that requires the
shutdown of a source. In other states,
we have approved state-adopted
requirements for the shutdown of a
source, which have usually been
negotiated between the source operator
and the state, and we have accordingly
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approved BART determinations that
took into account the resulting shorter
useful life of the affected source. In the
case of Dave Johnson Unit 3, the State
has not submitted a SIP revision to
require the shutdown that PacifiCorp
intends to implement, so there is no
enforceable shutdown commitment that
we can approve. We believe that
without an enforceable requirement for
the shutdown, we cannot make a BART
determination that reflects the shorter
planned useful life of the unit.
Therefore, we are incorporating the
shutdown requirement into one of the
two compliance paths available to
PacifiCorp, in order to allow it to only
be required to install and maintain the
less expensive LNBs/OFA emission
controls rather than the more expensive
SCR controls. We welcome a SIP
revision that would make the shutdown
requirement State law, and we would
withdraw the shutdown requirement
from the SIP upon approving such a SIP
revision.
2. Dave Johnston Unit 4
We proposed to require PacifiCorp
Dave Johnston Unit 4 to meet a FIP
emission limit of 0.12 lb/MMBtu (30day rolling average) for NOX BART
(assuming the installation of LNBs/OFA
with SNCR). Based on our revised costs
of compliance and visibility impacts, we
no longer conclude that NOX BART is
an emission limit of 0.12 lb/MMBtu (30day rolling average). Based on our new
cost and visibility improvement
numbers, we conclude that NOX BART
is represented by the SIP emission limit
of 0.15 lb/MMBtu (30-day rolling
average) for this unit. This emission
limit assumes the installation of LNBs/
OFA. As such, we are approving
Wyoming’s NOX BART determination
for Dave Johnston Unit 4.
3. Naughton Units 1 and 2
We proposed to require PacifiCorp
Naughton Units 1 and 2 to meet a FIP
emission limit of 0.07 lb/MMBtu (30day rolling average) for NOX BART
(assuming the installation of LNBs/OFA
with SCR). As detailed in the next
section, based on our revised costs of
compliance and visibility impacts, we
no longer conclude that NOX BART is
an emission limit of 0.07 lb/MMBtu (30day rolling average). Based on our new
cost and visibility improvement
numbers, we conclude that NOX BART
is represented by the SIP emission limit
of 0.26 lb/MMBtu (30-day rolling
average) for each unit. This emission
limit assumes the installation of LNBs/
OFA. As such, we are approving
Wyoming’s NOX BART determination
for Naughton Units 1 and 2.
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Sfmt 4700
5045
4. Naughton Unit 3
We proposed to approve the State’s
NOX BART determination for Naughton
Unit 3, which was an emission limit of
0.07 lb/MMBtu (30-day rolling average)
(assumes the installation of LNBs/OFA
with SCR). PacifiCorp submitted
comments on our proposed rulemaking
on August 26, 2013. In those comments,
PacifiCorp indicated (page 72) that
instead of installing SCR as required by
the SIP, it plans to convert Naughton
Unit 3 to natural gas in 2018 without
installation of any post-combustion
control of NOX emissions. Conversion to
natural gas in this manner can be
expected to result in NOX emissions that
are higher than the 0.07 lb/MMBtu limit
in the SIP combined with much lower
SO2 and PM emissions, with a
substantially lower overall remaining
impact on visibility. On July 5, 2013,
Wyoming issued Air Quality permit
MD–14506 to PacifiCorp that reflects the
conversion of Naughton Unit 3 to
natural gas in June of 2018. EPA met
with PacifiCorp on October 31, 2013, to
clarify the comments submitted by
PacifiCorp (see October 31, 2013 memo
to docket). PacifiCorp requested that
EPA include in its final action the
emission limits for SO2, PM, and NOX
that the State had in its permit MD–
14506 that it issued to PacifiCorp. EPA
supports PacifiCorp’s conversion of
Naughton Unit 3 to natural gas.
However, we have the authority and
obligation to take action on the SIP as
submitted by the State, and there is no
basis to disapprove the SIP. Since we
are approving the SIP, we do not have
authority to impose FIP limits even if
independently requested by a source.
Therefore, we cannot use the FIP to
relieve Naughton Unit 3 of the
obligation to achieve the 0.07 lb/MMBtu
NOX emission limit in the SIP nor to
impose emission limits for SO2 and PM
that reflect the planned conversion to
natural gas. Under the terms of the SIP,
the compliance deadlines for the
emission limits in the SIP for Naughton
Unit 3 do not become effective until five
years after our final action. We
understand that Wyoming intends to
submit a revision to their regional haze
SIP for Naughton Unit 3 that reflects the
BART NOX emission limits in its permit
MD–14506 as soon as practicable. EPA
intends to act on this SIP revision in an
expedited timeframe to reflect the
conversion of Naughton Unit 3 to
natural gas and a revised BART NOX
limit. In our final action we are
approving Wyoming’s NOX BART
determination for Naughton Unit 3. Our
regulatory language reflects the
following emission limit for Naughton
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Unit 3 for NOX: 0.07 lb/MMBtu (30-day
rolling average).
mstockstill on DSK4VPTVN1PROD with RULES2
5. Wyodak
We proposed to require PacifiCorp
Wyodak Unit 1 to meet a FIP emission
limit of 0.17 lb/MMBtu (30-day rolling
average) for NOX BART (assuming the
installation of LNBs/OFA with SNCR).
Based on our revised costs of
compliance and visibility impacts, as
well as comments received during the
public comment period (see section V),
we no longer conclude that NOX BART
is an emission limit of 0.17 lb/MMBtu
(30-day rolling average). Based on our
new cost and visibility improvement
numbers, we conclude that NOX BART
is a FIP emission limit of 0.07 lb/
MMBtu (30-day rolling average) for this
unit. This emission limit assumes the
installation of LNBs/OFA with SCR. As
detailed in the next section, based on
our weighing of the five factors, we find
that the average cost-effectiveness of
SCR ($4,036/ton) and the incremental
cost-effectiveness ($6,233/ton),
combined with a visibility improvement
of 0.61 deciviews at the most impacted
Class I area, makes the selection of SCR
for BART reasonable.
6. Jim Bridger
In our proposal, we proposed to
approve the State’s NOX BART and LTS
determinations for Jim Bridger Units 1
and 2. The State’s BART determination
required each unit to meet an emissions
limit of 0.26 lb/MMBtu (30-day rolling
average) within five years of our
approval of the SIP, based on new LNB
plus OFA. The LTS determination
required each unit to meet an emission
limit of 0.07 lb/MMBtu (30-day rolling
average) by December 31, 2022, and
December 31, 2021, respectively. EPA
proposed to approve these compliance
dates for numerous reasons as discussed
in detail in our proposed rulemaking. 78
FR 34755. We also proposed an
alternative FIP BART determination that
would require Jim Bridger Units 1 and
2 to meet an emission limit of 0.07 lb/
MMBtu (30-day rolling average) within
five years of our final rulemaking. 78 FR
34780. We are finalizing our proposed
approval of the State’s BART and LTS
determinations for Jim Bridger Units 1
and 2, although the reasons for our final
action on Jim Bridger Units 1 and 2 have
changed from our proposed action.
In our proposed rulemaking, we
stated:
EPA is proposing to determine that BART
for all units at Jim Bridger would be SCR if
the units were considered individually,
based on the five factors, without regard for
the controls being required at other units in
the PacifiCorp system. However, when the
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cost of BART controls at other PacifiCorp
owned EGUs is considered as part of the cost
factor for the Jim Bridger Units, EPA is
proposing that Wyoming’s determination that
NOX BART for these units is new LNB plus
OFA for is reasonable. Considering costs
broadly, it would be unreasonable to require
any further retrofits at this source within five
years of our final action. We note that the
CAA establishes five years at the longest
period that can be allowed for compliance
with BART emission limits.’’ 78 FR 34756.
However, as discussed in detail in section
V.D.2 below, we do not think PacifiCorp has
presented ample evidence to show that it
would be unreasonable or not feasible for
them to install numerous SCRs within the
five year BART period. Nonetheless, we are
approving the State’s BART determination
and LTS for Jim Bridger Units 1 and 2 based
on our consideration of the five factors, as
detailed in the next section.
We are approving the State’s SIP
requirement that Jim Bridger Units 1
and 2 meet an emission limit of 0.07 lb/
MMBtu (30-day rolling average) by 2022
and 2021, respectively. We are also
approving the State’s BART
determination that requires Jim Bridger
Units 1 and 2 to meet a NOX emission
limit of 0.26 lb/MMBtu (30-day rolling
average) within five years of our final
action.
For Jim Bridger Units 3 and 4 we
proposed to approve the SIP with regard
to the State’s determination that the
appropriate level of NOX control for
Units 3 and 4 for purposes of reasonable
progress is the SCR-based emission limit
in the SIP of 0.07 lb/MMBtu, with
compliance dates of December 31, 2015
for Unit 3 and December 31, 2016 for
Unit 4. In our proposal we noted that
since the State is requiring PacifiCorp to
install the LTS controls within the
timeline that BART controls would have
to be installed pursuant to 40 CFR
51.308(e)(iv), we proposed to approve
the State’s compliance schedule and
emission limit of 0.07 lb/MMBtu for Jim
Bridger Units 3 and 4 as meeting the
BART requirements.
We are finalizing our proposed
approval of the State’s BART and LTS
determinations for Jim Bridger Units 3
and 4, although, similar to Units 1 and
2, the reasons for our final action on
Units 3 and 4 have changed from our
proposed action.
7. Dave Johnston Units 1 and 2
We proposed to require PacifiCorp
Dave Johnston Units 1 and 2 to meet a
FIP emission limit of 0.22 lb/MMBtu
(30-day rolling average) for NOX under
reasonable progress (assuming the
installation of LNBs/OFA). As detailed
in the next section, based on our revised
costs and visibility impacts, we no
longer conclude that an emission limit
of 0.22 lb/MMBtu (30-day rolling
PO 00000
Frm 00016
Fmt 4701
Sfmt 4700
average) is warranted. We are approving
Wyoming’s NOX reasonable progress
determinations for Dave Johnston Units
1 and 2 (i.e., no controls).
IV. Basis for Our Final Action
We have fully considered all
significant comments on our proposal
and have concluded that no changes
from our proposal other than those
discussed in detail above are warranted.
Our action is based on an evaluation of
Wyoming’s regional haze SIP against the
regional haze requirements at 40 CFR
51.300–51.309 and CAA sections 169A
and 169B. All general SIP requirements
contained in CAA section 110, other
provisions of the CAA, and our
regulations applicable to this action
were also evaluated. The purpose of this
action is to ensure compliance with
these requirements. Our authority for
action on Wyoming’s SIP submittal is
based on CAA section 110(k). Our
authority to promulgate a FIP is based
on CAA section 110(c).
In our proposal, EPA asked interested
parties to provide additional
information on both our evaluation of
the BART factors and our proposed
determinations. 78 FR 38745. We
provided notice that any supplemental
information we received could lead us
to select BART control technologies or
compliance deadlines that differed from
our proposal. In response to this
request, we received extensive
comments on the visibility modeling
and cost estimates that we provided in
the proposal for NOX BART control
technologies. As a result of these
comments, we have revised our
visibility modeling and cost estimates.
The details of these changes and our
reasons for making them are provided
elsewhere in this document and in our
responses to the comments. Based on
these changes, we have reassessed our
proposed action on the State’s NOX
BART determinations for each of the
subject-to-BART sources by reevaluating the five statutory factors.16
We have also reassessed our proposed
action on the State’s NOX reasonable
progress determination for Dave
Johnston Units 1 and 2. In this section,
we describe in detail our reassessment
of the statutory factors for these sources
based on our revised visibility modeling
and cost estimates. For two sources—
Jim Bridger and Wyodak—we also
received additional comments,
explained below, that caused us to
16 We are finalizing our proposed approval of the
State’s PM BART determinations. We did not
receive any adverse comments that were sufficient
to convince us that reexamination of the State’s
control costs was warranted.
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reconsider certain aspects of our
decision for those sources.
EPA notes that, in considering the
visibility improvements reflected in our
revised modeling, EPA interprets the
BART Guidelines to require
consideration of the visibility
improvement from BART applied to the
entire BART-eligible source. The BART
Guidelines explain that, ‘‘[i]f the
emissions from the list of emissions
units at a stationary source exceed a
potential to emit of 250 tons per year for
any visibility-impairing pollutant, then
that collection of emissions units is a
BART-eligible source.’’ In other words,
the BART-eligible source (the list of
BART emissions units at a source) is the
collection of units for which one must
make a BART determination. The BART
Guidelines state ‘‘you must conduct a
visibility improvement determination
for the source(s) as part of the BART
determination.’’ This requires
consideration of the visibility
improvement from BART applied to the
BART-eligible source as a whole.
We note, however, that while our
regulations require states and EPA to
assess visibility improvement on a
source-wide basis, they provide
flexibility to also consider unit-specific
visibility improvement in order to more
fully inform the reasonableness of a
BART determination, but that does not
replace the consideration of visibility
benefit from the source (facility) as a
whole. In making the BART
determinations in this final action we
have considered visibility
improvements at the source, and then
also at the units that comprise the
source.
As explained in more detail later in
this decision, we received during the
comment period significant input on
expected costs associated with different
control technologies. We discuss in the
section above and in our response to
comments, the changes we made in
response to comments received on costs
of different control technologies. As
discussed above and in our response to
comments, we have revised our
modeling analysis in light of the input
we received during the public comment
period. This additional information and
analysis result in different costs and
visibility benefits, two of the five BART
factors. In some cases this leads us to
finalize our proposal, and in other cases
to reach a different conclusion.
This decision, which addresses
multiple facilities in a state where
numerous Class 1 areas are impacted to
a greater or lesser degree, illustrates
clearly the case-by-case nature of the
BART determination process. The
interplay among the five factors, and in
particular the cost and visibility factors,
is highly significant and determinative
of the outcome. In considering this
information, as we have noted in prior
decisions, our first assessment is
whether the state’s determination is
reasonable in light of the facts and
consistent with the requirements of the
Clean Air Act and implementing
regulations. If we determine that it is,
even if we might have reached a
different outcome if it were our decision
5047
to make in the first instance, we will
approve the SIP.
Below is a more specific discussion of
our determinations in the final decision.
As stated above more detailed
information on our determinations can
be found in the response to comments
sections of this rulemaking.
A. Laramie River
The State’s regional haze SIP
determined that NOX BART for Laramie
River Units 1, 2, and 3 is new LNB/
SOFA. We proposed to disapprove the
State’s determination because the State
neglected to reasonably assess the costs
of compliance and visibility
improvement in accordance with the
BART Guidelines. 78 FR 34766. After
revising the State’s costs and modeling
and re-evaluating the statutory factors,
we proposed to determine that NOX
BART is LNB/SOFA + SCR, with an
emissions limit of 0.07 lb/MMBtu for
each unit. We sought comment
generally on the BART factors and our
control determinations and indicated
that we could revise our control
determinations depending on any new
information that we received.
As the result of the comments
received on our proposal, we have
further revised our calculation of the
costs of compliance and visibility
modeling. We have considered any
comments on the other BART factors
but we have not changed our assessment
of the other BART factors. The revised
visibility modeling for the most
impacted Class I area (Badlands) is
presented in the following table.
TABLE 18—VISIBILITY MODELING FOR LARAMIE RIVER STATION
Laramie River Station
LNB/SOFA
LNB/SOFA + SNCR
LNB/SOFA + SCR
Unit 1 .....................................................
Unit 2 .....................................................
Unit 3 .....................................................
0.18 deciviews ......................................
0.18 deciviews ......................................
0.18 deciviews ......................................
0.28 deciviews ......................................
0.27 deciviews ......................................
0.27 deciviews ......................................
0.57 deciviews
0.53 deciviews
0.52 deciviews
Total * ..............................................
0.54 deciviews ......................................
0.82 deciviews ......................................
1.62 deciviews
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* The total visibility improvement was estimated as the sum of the visibility improvement from each unit.
We also considered the visibility
improvement at other impacted Class I
areas (Wind Cave, Rawah, and Rocky
Mountain), which range from 0.25 to
0.47 deciviews, 0.26 to 0.43 deciviews,
and 0.23 to 0.44 deciviews, for Units 1,
2, and 3, respectively. Further details
regarding our revised visibility
modeling and cost estimates were
provided in section III.A.
After re-evaluating the BART factors,
we continue to find that LNB/SOFA +
SCR is reasonable as BART and are
therefore finalizing our proposal. The
visibility improvement associated with
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LNB/SOFA + SCR at the most impacted
Class I area is significant on both a
source-wide (1.62 deciviews) and unitspecific (0.52–0.57 deciviews) basis.
The significant visibility improvement
at three other impacted Class I areas also
supports the selection of this option.
Finally, we believe that the incremental
visibility improvement at the most
impacted Class I area of SCR over SNCR
(nearly double in all cases) warrants the
selection of the most stringent control.
In regards to the costs of compliance,
we found that the revised average and
incremental cost-effectiveness of LNB/
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Fmt 4701
Sfmt 4700
SOFA + SCR is in line with what we
have found to be acceptable in our other
FIPs. The average cost-effectiveness per
unit ranges from $4,375 to $4,461/ton,
while the incremental cost-effectiveness
ranges from $5,449 to $5,871/ton. We
believe that these costs are reasonable,
especially in light of the significant
visibility improvement associated with
LNB/SOFA + SCR. As a result, we are
finalizing our proposed disapproval of
the State’s NOX BART determination for
Laramie River Station and finalizing our
proposed FIP that includes a NOX BART
determination of LNB/SOFA + SCR,
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with an emission limit of 0.07 lb/
MMBtu (30-day rolling average).
B. Jim Bridger
The State’s regional haze SIP
determined that NOX BART for Jim
Bridger Units 1–4 is new LNBs with
SOFA. The State also determined that
SCR should be installed at each unit as
part of the State’s long-term strategy to
achieve reasonable progress at several
Class I areas, and set compliance dates
of December 31, 2022, December 31,
2021, December 31, 2015, and December
31, 2016 for Units 1–4, respectively.
In our proposal, we indicated that the
State had neglected to reasonably assess
the costs of compliance and visibility
improvement for Jim Bridger in
accordance with the BART Guidelines.
We nonetheless proposed to approve the
State’s BART and reasonable progress
determinations for Units 3 and 4
because the compliance deadlines to
install SCR on these units were
sufficient to meet the requirements of
BART. We are now finalizing our
proposed action for Units 3 and 4.
We also proposed to approve the
State’s BART and reasonable progress
determinations for Units 1 and 2, but on
a different basis. There, we indicated
that given the number of SCR retrofits
PacifiCorp had to perform in Wyoming
and in other states, it might not be
affordable for PacifiCorp to install two
additional SCRs on Jim Bridger Units 1
and 2 within the five-year BART
compliance period. We requested
additional information from
commenters regarding whether the
affordability provisions of the BART
Guidelines should be applied to Units 1
and 2. In the alternative, we proposed
to find that NOX BART for Units 1 and
2 was an emission limit of 0.07 lb/
MMBtu (30-day rolling average) based
on the installation of LNB/SOFA + SCR
with a compliance deadline of five
years. Under this scenario, we
acknowledged that the costeffectiveness of LNB/SOFA + SCR at
Units 1 and 2 was within the range of
what EPA and the State itself had found
reasonable in other BART
determinations. We also considered the
significant visibility improvement
demonstrated by the State’s modeling to
warrant LNB/SOFA + SCR as BART.
Finally, we sought comment generally
on the BART factors and our control
determinations and indicated that we
could revise our control determinations
depending on any new information that
we received.
In response to our proposal, we
received both supportive and adverse
comments regarding whether the
affordability provisions of the BART
Guidelines should apply to Units 1 and
2. As explained in more detail in our
responses to these comments, we agree
that PacifiCorp did not make a sufficient
showing that it could not afford to
install LNB/SOFA + SCR on Units 1 and
2 within the five-year compliance
period. Nevertheless, we also received
new information regarding the costs of
compliance and visibility benefits
associated with Jim Bridger and have
revised our cost estimates and visibility
modeling for all four units accordingly.
We have considered any comments on
the other BART factors but we have not
changed our assessment of the other
BART factors.
The revised visibility modeling for the
most impacted Class I area (Bridger) is
presented in the following table (with
straight font representing modeled
results using an ammonia background
based on a monitored monthly varying
concentration, italicized font
representing modeled results using
IWAQM default 0.5 ppb background
ammonia).17
TABLE 19—VISIBILITY MODELING FOR JIM BRIDGER
Jim Bridger
Unit
Unit
Unit
Unit
1
2
3
4
LNB/SOFA
.................................................
.................................................
.................................................
.................................................
Total * .........................................
0.17/0.23
0.16/0.21
0.14/0.19
0.25/0.23
deciviews
deciviews
deciviews
deciviews
LNB/SOFA + SNCR
..........................
..........................
..........................
..........................
0.72/0.86 deciviews ..........................
0.20/0.27
0.19/0.25
0.17/0.23
0.30/0.28
deciviews
deciviews
deciviews
deciviews
..........................
..........................
..........................
..........................
0.86/1.03 deciviews ..........................
LNB/SOFA + SCR
0.27/0.37
0.27/0.36
0.26/0.35
0.45/0.42
deciviews
deciviews
deciviews
deciviews
1.25/1.5 deciviews
mstockstill on DSK4VPTVN1PROD with RULES2
* The total visibility improvement was estimated as the sum of the visibility improvement from each unit.
We also considered the visibility
improvements at other impacted Class I
areas (Bridger, Fitzpatrick, Rawah,
Rocky Mountain, Grand Teton, Teton,
Washakie, and Yellowstone), which
range from 0.26 to 0.91 deciviews, 0.26
to 0.89 deciviews, 0.24 to 0.87
deciviews, and 0.27 to 1.0 deciviews, for
Units 1–4, respectively. Further details
regarding our revised visibility
modeling and cost estimates are
provided in section III.A.
After re-evaluating the BART factors,
we are approving the State’s
determination that LNB/SOFA is NOX
BART for Units 1–4. The visibility
improvement associated with LNB/
SOFA + SCR at the most impacted Class
I area is significant on a source-wide
basis (1.25 to 1.5 deciviews). The fact
that Jim Bridger Station affects a number
of other Class I areas, which also would
see appreciable visibility improvement
with the installation of LNB/SOFA +
SCR, also weighs in favor of selecting
this option as BART. The unit-specific
benefits for Units 1 and 2 are somewhat
more modest (0.27–0.37 deciviews),
however, especially considering the low
incremental improvement over SNCR
(0.07–0.11 deciviews). The incremental
visibility improvement of SNCR over
LNB/SOFA is even smaller (0.03–0.04
deciviews).
In regards to the costs of compliance,
we found that the revised average costeffectiveness of LNB/SOFA + SCR is in
line with what we have found to be
acceptable in our other FIPs. The
average cost-effectiveness is $4,088 and
$4,461/ton at Units 1 and 2,
respectively. The incremental costeffectiveness, on the other hand, is on
the high end of what we have found to
be reasonable in our other FIPs. The
incremental cost-effectiveness is $7,477
and $8,986/ ton at Units 1 and 2,
respectively.
Ultimately however, while we believe
that these costs and visibility
improvements could potentially justify
LNB/SOFA + SCR as BART, because
this is a close call and because the State
has chosen to require SCR as a
reasonable progress control, we believe
deference to the State is appropriate in
this instance. We are therefore finalizing
17 Air Quality Modeling Protocol: Wyoming
Regional Haze Federal Implementation Plan, U.S.
EPA, January, 2014.
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our approval of the State’s
determination to require SCR at Jim
Bridger Units 1–4, with an emission
limit of 0.07 lb/MMBtu (30-day rolling
average), as part of its long-term
strategy. We are also finalizing our
approval of the compliance dates of
December 31, 2022, December 31, 2021,
December 31, 2015, and December 31,
2016 for Units 1- 4 respectively.
C. Dave Johnston Units 3 and 4
The State’s regional haze SIP
determined that NOX BART for Dave
Johnston Units 3 and 4 is LNB/OFA. We
proposed to disapprove the State’s
determination because the State
neglected to reasonably assess the costs
of compliance and visibility
improvement in accordance with the
BART Guidelines. 78 FR 34778. After
revising the State’s costs and modeling
and re-evaluating the statutory factors,
we proposed to determine that NOX
BART for Unit 3 is LNB/SOFA + SCR,
with an emission limit of 0.07 lb/
MMBtu (30-day rolling average). We
proposed that NOX BART for Unit 4 is
LNB/SOFA + SNCR, with an emission
limit of 0.12 lb/ MMBtu. We sought
comment generally on the BART factors
5049
and our control determinations and
indicated that we could revise our
control determinations depending on
any new information that we received.
As the result of the comments
received on our proposal, we have
further revised our calculation of the
costs of compliance and visibility
modeling. We have considered any
comments on the other BART factors
but we have not changed our assessment
of the other BART factors. The revised
visibility modeling for the most
impacted Class I area (Wind Cave) is
presented in the following table.
TABLE 20—VISIBILITY MODELING FOR DAVE JOHNSTON (BART UNITS)
Dave Johnston
LNB/OFA
LNB/OFA + SNCR
LNB/OFA + SCR
Unit 3 .....................................................
Unit 4 .....................................................
0.33 deciviews ......................................
0.41 deciviews ......................................
0.39 deciviews ......................................
0.46 deciviews ......................................
0.51 deciviews
0.57 deciviews
Total * ..............................................
0.74 deciviews ......................................
0.85 deciviews ......................................
1.08 deciviews
mstockstill on DSK4VPTVN1PROD with RULES2
* The total visibility improvement was estimated as the sum of the visibility improvement from each unit.
We also considered the visibility
improvement at other impacted Class I
areas (Badlands, Mt Zirkel, Rawah, and
Rocky Mountain), which range from
0.20 to 0.47 deciviews and 0.24 to 0.55
deciviews, for Units 3 and 4,
respectively. Further details regarding
our revised visibility modeling and cost
estimates were provided in section III.A.
After re-evaluating the BART factors,
we no longer believe that LNB/OFA +
SNCR is NOX BART for Dave Johnston
Unit 4. As we explained in the proposal,
the incremental cost-effectiveness of
LNB/OFA + SCR was and continues to
be excessive ($13,312), so we have
eliminated this control option. While
the revised average and incremental
costs of LNB/OFA + SNCR continue to
be reasonable, the incremental visibility
improvement of SNCR over LNB/OFA is
now only 0.05 deciviews. In light of this
new visibility information, we believe
that the State’s determination that LNB/
OFA is NOX BART for Unit 4 was
reasonable and are approving it
accordingly.
In regards to Dave Johnston Unit 3, we
continue to believe that LNB/OFA +
SCR is NOX BART. The visibility
improvement associated with LNB/
SOFA + SCR at the most impacted Class
I area is significant (0.51 deciviews).
The visibility improvement at several
other impacted Class I areas also
supports the selection of this option.
Finally, we do not believe that the
incremental visibility improvement at
the most impacted Class I area of SCR
over SNCR (0.12 deciviews) is
sufficiently insignificant to warrant the
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elimination of the most stringent control
in this instance.
In regards to the costs of compliance,
we found that the revised average and
incremental cost-effectiveness of LNB/
SOFA + SCR is in line with what we
have found to be acceptable in our other
FIPs. The average cost-effectiveness is
$2,635/ton, while the incremental costeffectiveness is $7,583/ton. We believe
that these costs are reasonable,
especially in light of the significant
visibility improvement associated with
LNB/SOFA + SCR.
In response to other comments we
received, we also considered an
alternative BART analysis for Unit 3
based on PacifiCorp’s commitment to
retire Unit 3 by 2027 in lieu of installing
SCR. Using a 9-year remaining useful
life as the amortization period for Unit
3, the incremental cost-effectiveness of
LNB/OFA + SCR becomes excessive
($11,781). Furthermore, the incremental
visibility improvement at the most
impacted Class I area from use of LNB/
OFA to use of LNB/OFA+ SNCR is only
0.06 deciviews. Thus, taking all five
factors into account, including the
remaining useful life of nine years, we
conclude that the NOX BART would be
LNB/OFA in this scenario.
To provide flexibility, we are
finalizing both scenarios in a FIP for
Dave Johnston Unit 3. Under the first
scenario, we are finalizing a NOX BART
determination of LNB/OFA + SCR, with
an emission limit of 0.07 lbs/ MMBtu
(30-day rolling average). Under the
alternative scenario, based on a
commitment to retire Unit 3 by 2027, we
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are finalizing a NOX BART
determination of LNB/OFA, with an
emission limit of 0.28 lbs/ MMBtu (30day rolling average).
D. Naughton
The State’s regional haze SIP
determined that NOX BART is new
LNB/OFA for Naughton Units 1 and 2
and LNB/OFA + SCR for Naughton Unit
3. We proposed to approve the State’s
determination for Unit 3, but proposed
to disapprove the State’s determination
for Units 1 and 2 because the State
neglected to reasonably assess the costs
of compliance and visibility
improvement in accordance with the
BART Guidelines. 78 FR 34748. After
revising the State’s costs and modeling
and re-evaluating the statutory factors,
we proposed to determine that NOX
BART for Units 1 and 2 is LNB/SOFA
+ SCR, with an emissions limit of 0.07
lb/MMBtu for each unit. We sought
comment generally on the BART factors
and our control determinations and
indicated that we could revise our
control determinations depending on
any new information that we received.
As the result of the comments
received on our proposal, we have
further revised our calculation of the
costs of compliance and visibility
modeling. We have considered any
comments on the other BART factors
but we have not changed our assessment
of the other BART factors. The revised
visibility modeling for the most
impacted Class I area (Bridger) is
presented in the following table (with
straight font representing modeled
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results using an ammonia background
based on a monitored monthly varying
concentration, italicized font
representing modeled results using
IWAQM default 0.5 ppb background
ammonia).
TABLE 21—VISIBILITY MODELING FOR NAUGHTON
Naughton
LNB/OFA
LNB/OFA + SNCR
LNB/OFA + SCR
Unit 1 .............................................
Unit 2 .............................................
Unit 3 .............................................
0.22/0.26 deciviews ......................
0.28/0.32 deciviews ......................
0.05/0.07 deciviews ......................
0.26/0.30 deciviews ......................
0.34/0.38 deciviews ......................
0.20/0.29 deciviews ......................
0.33/0.39 deciviews.
0.42/0.46 deciviews.
0.49/0.60 deciviews.
Total * ......................................
0.55/0.65 deciviews ......................
0.80/0.97 deciviews ......................
1.24/1.45 deciviews
* The total visibility improvement was estimated as the sum of the visibility improvement from each unit.
We also considered the visibility
improvement at other impacted Class I
areas (Fitzpatrick, North Absaroka,
Washakie, Teton, Grand Teton, and
Yellowstone), which range from 0.10 to
0.30 deciviews, 0.08 to 0.42 deciviews,
and 0.13 to 0.49 deciviews, for Units 1,
2, and 3, respectively. Further details
regarding our revised visibility
modeling and cost estimates were
provided in section III.A.
After re-evaluating the BART factors,
we no longer believe that LNB/OFA +
SCR is NOX BART for Naughton Units
1 and 2. The visibility improvement
associated with LNB/SOFA + SCR at the
most impacted Class I area remains
significant on a source-wide basis (1.24–
1.45 deciviews) but more modest on a
unit-specific basis (0.33–0.46
deciviews). The visibility improvement
at six other impacted Class I areas
continues to support the selection of
this option as well. In regards to the
costs of compliance, however, we found
that while the revised average costeffectiveness values for LNB/OFA + SCR
were acceptable, the revised
incremental cost-effectiveness values
were beyond the upper end of the range
(higher even than Jim Bridger) of what
we have found to be acceptable in our
other FIPs. For Units 1 and 2,
respectively, the average costeffectiveness per unit is $3,109 and
$2,566/ ton, while the incremental costeffectiveness is $10,384 and $8,440/ ton.
Consequently, we believe that it was not
unreasonable for the State to reject LNB/
OFA + SCR as BART. Furthermore, we
cannot say the State acted unreasonably
in rejecting LNB/OFA + SNCR at Units
1 and 2 because the incremental
visibility improvement of SNCR over
LNB/OFA, while possibly appreciable,
is very low at just 0.10 deciviews across
both units. Therefore, based on our
analysis we believe that the State’s
determination that LNB/OFA is NOX
BART for Units 1 and 2, with an
emission limit of 0.28 lbs/ MMBtu, was
ultimately reasonable and are approving
it accordingly.
E. Wyodak
The State’s regional haze SIP
determined that NOX BART for Wyodak
Unit 1 is new LNBs with OFA. We
proposed to disapprove the State’s
determination because the State
neglected to reasonably assess the costs
of compliance and visibility
improvement in accordance with the
BART Guidelines. 78 FR 34784–34785.
As a result, we also proposed a FIP for
NOX BART. After considering the BART
factors, we noted that the costeffectiveness and visibility
improvement of the most stringent
control option, LNB/OFA + SCR, were
within the range of values that EPA had
found reasonable in other FIPs.
However, we proposed not to require
LNB/OFA + SCR as NOX BART for
Wyodak Unit 1. Instead, we proposed to
require LNB/OFA + SNCR based on the
reasoning that the cumulative visibility
improvement of SCR across all Class I
areas was low when compared to the
cumulative visibility improvement
associated with SCR at Dave Johnston
Unit 3, Laramie River Units 1–3, and
Naughton Units 1 and 2. We sought
comment generally on the BART factors
and our control determinations and
indicated that we could revise our
control determinations depending on
any new information that we received.
Based on our discussion of LNB/OFA +
SCR at Wyodak, that control option was
among those that we invited comment
on.
In response to our proposal for
Wyodak, we received comments that
cumulative visibility improvement
should not be used as a basis to reject
a control option that has already been
deemed reasonable based on visibility
improvement at the most impacted
Class I area. The commenters pointed
out that such an approach would have
the illogical effect of allowing an added
benefit (visibility improvement at
multiple Class I areas) to weigh in favor
of less stringent controls. We agree with
this criticism and want to make clear
today that where a control is warranted
as BART based on the costs of controls
and visibility benefits at the most
impacted area alone, cumulative
visibility benefits can only strengthen
the case for that control, not suggest that
it is unwarranted. Similarly, where a
control might not be warranted as BART
based on the improvement at a single
Class I area, significant cumulative
benefits are an additional consideration
that could warrant that the control be
selected as BART.
In addition, we have further revised
our calculation of the costs of
compliance and visibility modeling for
Wyodak Unit 1. We have not changed
our assessment of the other BART
factors. The revised visibility modeling
for the most impacted Class I area (Wind
Cave) is presented in the following
table.
TABLE 22—VISIBILITY MODELING FOR WYODAK
mstockstill on DSK4VPTVN1PROD with RULES2
Wyodak
LNB/SOFA
LNB/SOFA + SNCR
Unit 1 .....................................................
0.21 deciviews ......................................
0.32 deciviews ......................................
We also considered the visibility
improvement at a second impacted
Class I area (Badlands), which is a
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maximum of 0.38 deciviews for LNB/
SOFA + SCR. Further details regarding
our revised visibility modeling and cost
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LNB/SOFA + SCR
0.61 deciviews.
estimates were provided in the previous
section.
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After re-evaluating the BART factors
and dismissing our earlier rationale for
rejecting an otherwise reasonable
control, we find that LNB/SOFA + SCR
is reasonable as BART. As the BARTeligible source in this case is a single
unit, the source-wide and unit-specific
visibility improvements associated with
the various control options are the same.
The visibility improvement associated
with LNB/SOFA + SCR at the most
impacted Class I area (0.61 deciviews) is
significant. There is also a more modest
visibility improvement (0.38 deciviews)
at a second impacted Class I area that
supports the selection of this option.
Finally, we believe that the incremental
visibility improvement at the most
impacted Class I area of SCR over SNCR
(nearly double) warrants the selection of
the most stringent control.
In regards to the costs of compliance,
we found that the revised average and
incremental cost-effectiveness of LNB/
SOFA + SCR is in line with what we
have found to be acceptable in our other
FIPs. The average cost-effectiveness is
$4,036/ton, while the incremental costeffectiveness of SCR over SNCR is
$6,223/ton. We believe that these costs
are reasonable, especially in light of the
significant visibility improvement
associated with LNB/SOFA + SCR at
Wind Cave. As a result, we are
finalizing our proposed disapproval of
the State’s NOX BART determination for
Wyodak Unit 1. Additionally, after
carefully considering adverse
comments, we have decided not to
finalize our proposed NOX
determination of LNB/SOFA + SNCR,
but rather are finalizing a NOX BART
determination of LNB/SOFA + SCR,
with an emission limit of 0.07 lb/
MMBtu (30-day rolling average).
F. Dave Johnston Units 1 and 2
(Reasonable Progress)
We proposed to disapprove the State’s
determination to not impose LNB/OFA
as reasonable progress controls for NOX
at Dave Johnston Units 1 and 2. Based
on our original cost estimates and
visibility modeling, we also proposed to
require PacifiCorp Dave Johnston Units
1 and 2 to meet a FIP emission limit of
0.22 lb/MMBtu (30-day rolling average)
(assuming the installation of LNB/OFA).
Based on our revised cost estimates and
visibility modeling that we developed in
response to comments, however, we no
longer conclude that reasonable
progress controls are warranted this
planning period. While we continue to
disagree with the State’s reasoning for
not imposing controls (as detailed in our
response to comments), we are not
prepared to say the State’s ultimate
decision was unreasonable. In
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evaluating the four reasonable progress
factors and the visibility improvement
associated with potential controls, we
found that the average and incremental
cost-effectiveness of LNB/OFA ($990/
ton and $1,221/ton, respectively), while
reasonable if viewed in isolation, was
not necessarily justified this planning
period in light of the relatively modest
visibility improvement predicted by the
revised modeling (0.11 deciviews—0.12
deciviews at the most impacted Class I
area). As a result, we are approving the
State’s reasonable progress
determination of no new controls for
Dave Johnston Units 1 and 2, but we
expect the State to revisit the issue
during the next planning period.
V. Issues Raised by Commenters and
EPA’s Responses
A. Legal Issues
1. EPA Authority and State Discretion
Comment: Multiple commenters
stated that CAA Section 169A and the
Regional Haze Rule (RHR) give the
states the lead in developing their
regional haze SIPs. Some commenters
went further in stating that Wyoming is
given almost complete discretion in
creating its regional haze SIP. These
commenters argued that, because
Wyoming is given such discretion, EPA
lacks the statutory authority to
disapprove the State’s regional haze SIP.
Specifically, some commenters pointed
to the flexibility the State is granted in
developing its BART determinations
and other RHR requirements. The
commenters stated that the CAA
anticipates that EPA will create
guidance and that the states, using their
discretion, will use this guidance to
develop regional haze SIPs. The State of
Wyoming and other parties argued that
each factor in the five-factor analysis
used to make its BART determinations
was appropriately weighed based on the
State’s own discretion. The commenters
therefore argue that EPA has no basis on
which to disapprove the five-factor
analysis and that EPA does not have
authority to reject a state’s BART
determination solely because EPA
would have conducted the analysis in a
different way or reached a different
conclusion. The commenters went on to
say that the State, after considering all
statutory factors, made BART
determinations for all subject-to-BART
sources in a manner consistent with 40
CFR Part 51 Appendix Y, the
established CAA requirements, and the
interests of the State of Wyoming.
Numerous commenters went on to say
that the U.S. Court of Appeals for the
D.C. Circuit has affirmed that EPA’s role
in determining BART is limited and that
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5051
a state’s role is paramount. The court
found that the CAA ‘‘calls for states to
play the lead role in designing and
implementing regional haze programs.’’
Am. Corn Growers Ass’n v. EPA, 291
F.3d 1, 2 (D.C. Cir. 2002). The
commenters stated that the court also
reversed a portion of EPA’s original
RHR because it found that EPA’s
method of analyzing visibility
improvements distorted the statutory
BART factors and was ‘‘inconsistent
with the Act’s provisions giving the
states broad authority over BART
determinations.’’ Id., see also Utility Air
Regulatory Group v. EPA, 471 F.3d
1333, 1336 (D.C. Cir. 2006) (The second
step in a BART determination ‘‘requires
states to determine the particular
technology that an individual source
‘subject to BART’ must install.’’).
The commenters asserted that states
have the primary responsibility for
preventing air pollution under the CAA.
CAA section 101(a)(3), 42 U.S.C.
7401(a)(3). Pursuant to this principle,
states, not EPA, have always had
primary control over decisions to
impose specific emission limits (and
therefore specific pollution control
technologies) for individual facilities.
By congressional design, EPA ‘‘is
relegated . . . to a secondary role in the
process of determining and enforcing
the specific, source-by-source emission
limitations which are necessary [to
meet] national standards.’’ Train v.
NRDC, 421 U.S. 60, 79 (1975). This
basic division of responsibilities
between EPA and the states remained
unchanged when Congress amended the
Act in 1977 and again in 1990. See
Virginia v. EPA, 108 F.3d 1397, 1408–
09 (D.C. Cir. 1997).
Response: Congress crafted the CAA
to provide for states to take the lead in
developing SIPs, but balanced that
decision by requiring EPA to review the
SIPs to determine whether they meet the
requirements of the CAA. EPA’s review
of SIPs is not limited to a ministerial
type of automatic approval of a state’s
decisions. See North Dakota v. EPA, 730
F.3d 750, 760–61 (8th Cir. 2013)
(‘‘Although the CAA grants states the
primary role of determining the
appropriate pollution controls within
their borders, EPA is left with more than
the ministerial task of routinely
approving SIP submissions.’’)
(hereinafter ‘‘North Dakota’’). EPA must
consider not only whether the State
considered the appropriate factors, but
whether the State acted reasonably in
doing so. In undertaking such a review,
EPA does not ‘‘usurp’’ the State’s
authority, but ensures that such
authority is reasonably exercised. EPA
has the authority to issue a FIP either
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when EPA has made a finding that the
state has failed to timely submit a SIP
or when EPA has found a SIP deficient.
Here, EPA has authority on both
grounds, and we have approved as
much of the Wyoming regional haze SIP
as possible, while promulgating a FIP
only to fill the remaining gaps. Our
action today is consistent with the
statute.
Our action does not contradict the
Supreme Court’s decision in Train.
States have significant responsibilities
in the implementation of the CAA and
meeting the requirements of the RHR.
We recognize that states have the
primary responsibility of drafting a SIP
to address the requirements of the
CAA’s visibility program. We also
recognize that we have the
responsibility of ensuring that SIPs,
including regional haze SIPs, conform to
CAA requirements. We cannot approve
a regional haze SIP that fails to address
BART with a reasoned consideration of
the statutory and regulatory
requirements of the CAA and the RHR.
See Oklahoma v. EPA, 723 F.3d 1201,
1207 (10th Cir. 2013) (‘‘We agree with
the EPA that the statute provides the
agency with the power to review
Oklahoma’s BART determination for
these four units.’’) (hereinafter
‘‘Oklahoma’’).
Contrary to the commenters’
assertions, we recognize the State’s
primary responsibility in drafting a SIP.
In fact, we have approved many of the
State’s determinations, including the
entirety of Wyoming’s Section 309
BART alternative for SO2 emissions. We
are disapproving the State’s NOX BART
determinations, as the CAA requires,
because the State neglected to properly
consider the costs of compliance and
the visibility benefits associated with
several of the available control options.
We also disagree that our proposal is
inconsistent with the American Corn
Growers and Utility Air Regulatory
Group decisions. These cases dealt with
EPA’s authority to issue broad
regulations that prescribed how states
must conduct their BART
determinations. They did not address
EPA’s authority to review regional haze
SIPs for compliance with the mandates
of the CAA or EPA’s now finalized
implementing regulations. The Tenth
Circuit, in concluding that EPA had
authority to disapprove a BART
determination that did not follow the
BART Guidelines, stated that the
American Corn Growers opinion ‘‘does
not alter this conclusion.’’ Oklahoma v.
EPA, 723 F.3d 1201, 1208 (10th Cir.
2013).
Because the CAA sets certain
mandatory statutory deadlines and
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provides for citizen suits when the
Administrator fails to perform a
mandatory duty, we are required by the
terms of a consent decree to ensure that
Wyoming’s CAA requirements for
regional haze are finalized by January
10, 2014. Because we have found that
the State’s regional haze SIP did not
satisfy CAA and RHR requirements in
full and because we have previously
found that Wyoming failed to timely
submit its regional haze SIP, we have
not only the authority, but a statutory
duty to promulgate a FIP that meets
those requirements. We have reviewed
this decision in light of other decisions
made by us, as well as decisions made
in other states SIPs. Our action today in
large part approves the regional haze
SIP submitted by Wyoming. Our
disapproval of Wyoming’s NOX BART
and reasonable progress determinations
and imposition of a FIP is not intended
to encroach on State authority. Rather,
our action today is required by the CAA
to ensure that the State has a complete
plan in place to address the CAA’s
visibility requirements.
Comment: The fact that Congress gave
states primacy in making BART
determinations is noteworthy and
related to the fact that the regional haze
program is focused on an aesthetic
benefit, not a public health standard.
Under other sections of the CAA,
primarily those dealing with healthbased standards, Congress directed EPA
to establish standards that do not take
costs into consideration. States then
develop plans to meet those healthbased standards. Under the New Source
Performance Standards program (section
111 of the CAA) and National Emission
Standards for Hazardous Air Pollutants
program (section 112), EPA routinely
establishes specific emission limits for
large industrial sources. The regional
haze program, which deals with an
aesthetic standard, was clearly laid out
by Congress to be different in its
approach, to avoid establishing
emission limits, to give states authority
to decide appropriate controls, and
allow states to weigh the costs against
the benefits.
Response: We do not agree with this
commenter’s characterization of the
regional haze program or the CAA’s
visibility requirements. While it is true
that the goal of CAA sections 169A and
169B is to improve visibility in national
parks and wilderness areas rather than
to prevent adverse human health effects,
Congress structured the program so that
states’ decisions had to be made in the
form of SIPs, which EPA has the
authority to review for compliance with
all CAA requirements. Furthermore,
Congress did not create an approach
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that would allow states to avoid
establishing emission limits. On the
contrary, Congress specifically directed
EPA’s regulations to require states to
devise ‘‘emission limits . . . necessary
to make reasonable progress,’’ CAA
section 169A(b)(2), including the
requirement to establish BART, which
the RHR defines as ‘‘an emission
limitation.’’ 40 CFR 51.301.
Comment: EPA’s actions leave
nothing under the CAA’s framework by
which Wyoming could make an
approvable BART determination. EPA
has overreached and exceeded its
statutory authority by proposing a FIP
that replaces Wyoming’s considered
judgment with EPA’s priorities and
policy choices.
Response: We disagree with this
comment. EPA is not substituting its
judgment for that of the State of
Wyoming or issuing a FIP merely to
advance priorities and policy choices.
Rather, we have determined that
Wyoming did not properly follow the
BART Guidelines or the CCM in
conducting its BART analyses and,
therefore, did not correctly consider the
costs of compliance or the visibility
benefits associated with available
control technologies as the CAA
requires. Consequently, we are
finalizing a FIP in today’s action to
remedy the gaps left by these
inadequacies. We note, however, that
the CAA’s framework provides
Wyoming with the opportunity to
submit a SIP revision at any time that
could replace all or a portion of EPA’s
FIP, and we encourage Wyoming to do
so.
Comment: EPA clearly gave the states
more discretion through rulemaking
when it split the universe of BART
sources impacted by the BART
Guidelines into power plants greater
than 750 megawatts (MW) and all
others. States were merely encouraged
to follow the BART Guidelines for the
smaller BART sources. EPA says in the
preamble ‘‘that states should view the
guidelines as helpful guidance for these
other categories.’’ In saying this, EPA is
affording even more discretion to the
states in making BART determinations
for the smaller BART sources. EPA has
proposed disapproval of Wyoming’s
BART determination and proposed a
FIP for one of these smaller sources, the
Wyodak Unit 1 335 MW power plant.
The State believes that the EPA is again
overreaching in its action by proposing
a FIP for Wyodak Unit 1, where
Wyoming was not even required to
follow the BART Guidelines in arriving
at its BART determination.
Response: We agree that the BART
Guidelines are only mandatory for
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‘‘fossil-fuel fired power plants having a
total generating capacity greater than
750 megawatts.’’ 40 CFR
51.308(e)(1)(ii)(B). However, the fact
that a state may deviate from the
procedures in the BART Guidelines
when selecting BART for smaller EGUs
does not mean that a state has
unfettered discretion to act
unreasonably or inconsistently with the
CAA or the RHR. Ultimately, a state
must still adopt the ‘‘best available
retrofit technology,’’ CAA section
169A(b)(2)B); 40 CFR 51.308(e)(1)(ii)(A),
while reasonably considering the five
statutory factors.
The RHR further defines BART to
mean ‘‘an emission limitation based on
the degree of reduction achievable
through the application of the best
system of continuous emission
reduction for each pollutant which is
emitted by an existing stationary
facility.’’ 40 CFR 51.301 (emphasis
added). We do not interpret this
requirement to allow a state to dismiss
the best system of continuous emission
reduction under the mantle of unlimited
state discretion. As we discuss
elsewhere in this document, Wyoming
erroneously evaluated costs and
visibility benefits when analyzing the
various control options available for
Wyodak, and thereby did not reasonably
consider the statutory factors and select
the best system of control.
Comment: EPA’s RHR gave states the
flexibility to choose alternatives to the
BART process, such as participation in
a trading program. EPA spells out in the
preamble that this ‘‘substantial
flexibility’’ provides the ‘‘states the
ability to choose the least costly and
least burdensome alternative.’’ EPA and
28 states on the east coast took
advantage of this flexibility when it
declared that the cap and trade program
for ozone nonattainment would, for the
most part, satisfy the requirements of
BART. The important point here is that
EPA wanted and pushed for flexible,
cost-savings approaches to address
regional haze. EPA is still pushing for
approval of the Cross States Air
Pollution Rule (CSAPR) as a solution to
regional haze problems on the east
coast.
There appears to be a consistency
issue within the EPA over the
application of flexibility. Wyoming does
not think EPA meant for an approach to
promote costs savings and less
burdensome solutions to be restricted to
one area of the country or certain types
of solutions. However, EPA’s proposal
to partially disapprove Wyoming’s
regional haze SIP and impose more
costly and burdensome FIP
requirements for seven BART units in
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the State of Wyoming appear to be
inconsistent with EPA’s purported
‘‘substantial flexibility.’’ EPA’s failure to
recognize Wyoming’s discretion in these
areas is arbitrary and capricious.
Response: Wyoming had the
opportunity to submit better-than-BART
alternatives in lieu of source-specific
NOX BART determinations. Wyoming
did not do so. Because Wyoming did not
take advantage of the flexibility afforded
by better-than-BART alternatives, we
must review Wyoming’s BART
determinations for compliance with the
applicable requirements of the CAA,
RHR, and BART Guidelines. Our
proposal clearly laid out the bases for
our proposed disapproval of the State’s
NOX BART determinations, and we
have relied on the standards contained
in our regulations and the authority that
Congress granted us to review and
determine whether Wyoming’s regional
haze SIP complied with the minimum
statutory and regulatory requirements.
To the extent a cost analysis relies on
values that are inaccurate, a state has
not considered cost in a reasoned or
reasonable fashion. To the extent a state
has considered visibility improvement
from potential emissions controls in a
way that substantially understates the
improvement or does so in a way that
is not consistent with the CAA, the state
has not considered visibility
improvement in a reasoned or
reasonable fashion. In these
circumstances—as discussed in more
detail in the proposed notice and this
final notice—EPA is required to
disapprove the relevant aspects of the
SIP. In determining SIP adequacy, we
must exercise our judgment and
expertise regarding complex technical
issues, and it is entirely appropriate that
we do so. Courts have recognized this
necessity and deferred to our exercise of
discretion when reviewing SIPs. See,
e.g., Connecticut Fund for the Env’t.,
Inc. v. EPA, 696 F.2d 169 (2nd Cir.
1982); Michigan Dep’t. of Envtl. Quality
v. Browner, 230 F.3d 181 (6th Cir. 2000);
Mont. Sulphur & Chem. Co. v. EPA,
2012 U.S. App. LEXIS 1056 (9th Cir.
Jan. 19, 2012).
Comment: One commenter asserted
that the U.S. Court of Appeals for the
D.C. Circuit’s decision to vacate CSAPR
is relevant to the Wyoming FIP. EME
Homer City Generation, L.P. v. EPA.,
696 F.3d 7 (D.C. Cir. 2012), cert. granted
570 U.S. (June 24, 2013) (No. 12–1182)
(CSPAR Decision), and stated that EPA’s
proposed Wyoming FIP exceeds EPA’s
statutory authority. The commenter also
states that in vacating CSAPR, the D.C.
Circuit held that EPA’s ‘‘FIP-first’’
approach exceeds EPA’s authority
because EPA issued a FIP at the same
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5053
time it determined the emission
reduction parameters that the states
were supposed to implement. The
commenter stated that EPA’s theory was
that EPA can define the end goals and
simultaneously issue federal plans to
implement them, upending that process
and placing the Federal Government
firmly in the driver’s seat at both steps.
Other commenters stated that the D.C.
Circuit’s rejection of the CSAPR rule is
irrelevant to EPA’s regional haze
rulemaking for Wyoming. They asserted
that the regional haze program differs
from the CAA’s good-neighbor provision
in fundamental ways that make the
court’s rejection of CSAPR irrelevant to
EPA’s action on Wyoming’s regional
haze plan. The commenters stated that
the CAA’s visibility provisions establish
a technology-based standard for eligible
major sources, including PacifiCorp’s
coal-fired power plants in Wyoming.
See 42 U.S.C. 7491(b)(2)(A). To help
achieve ‘‘reasonable progress’’ toward
the national visibility goal, eligible
sources must install BART for hazecausing pollutants. Id. BART is defined
as: ‘‘an emission limitation based on the
degree of reduction achievable through
the application of the best system of
continuous emission reduction for each
pollutant which is emitted by an
existing stationary facility.’’ 40 CFR
51.301. The emission limitation must be
established on a case-by-case basis,
taking into consideration the technology
available, the costs of compliance, the
energy and non-air quality
environmental impacts of compliance,
any pollution control equipment in use
or in existence at the source, the
remaining useful life of the source, and
the degree of improvement in visibility
which may reasonably be anticipated to
result from the use of such technology.
Unlike the D.C. Circuit’s interpretation
of the good-neighbor provision, the
BART definition establishes a floor for
emissions reductions, but no ceiling.
States must ensure that eligible sources
install the best pollution control
devices.
These commenters also argued that
when a SIP fails to establish a program
that meets CAA requirements, then EPA
has an obligation to promulgate a FIP.
Here, they argued, EPA carried out its
statutory duty in proposing a partial FIP
for Wyoming. EPA’s role is not mere
‘‘rubber-stamping’’ of poor SIPs. EPA
‘‘has a duty to evaluate the adequacy of
the existing SIP as a whole when
approving SIP revisions.’’ Ass’n of
Irritated Residents v. EPA, 632 F.3d 584,
591 (9th Cir. 2011). A FIP ‘‘fill[s] all or
a portion of a gap or otherwise correct[s]
all or a portion of an inadequacy in a
State implementation plan.’’ 42 U.S.C.
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7602(y) (emphasis added). In proposing
to reject many of Wyoming’s inadequate
BART determinations, and proposing a
partial FIP, EPA is merely acting to
fulfill its own regulatory obligations
under the Act.
Response: With respect to the
comment that we lacked authority to
promulgate a FIP due to the D.C.
Circuit’s decision in EME Homer City,
we disagree. In EME Homer City, the
D.C. Circuit vacated CSAPR, which was
promulgated by EPA to address
interstate transport of SO2 and NOX
under CAA section 110(a)(2)(D). The
court found that CSAPR exceeded EPA’s
authority under section 110 because the
rule had the potential to require upwind
States to reduce emissions by more than
their own significant contributions to
downwind nonattainment and because
EPA had not given states an opportunity
to submit SIPs after EPA had quantified
their obligations for emissions
reductions.
In the regional haze context, by
contrast, EPA defined states’ obligations
under the RHR and the BART
Guidelines well in advance of its
findings of failure to submit and
subsequent SIP disapprovals. EPA
promulgated the original RHR on July 1,
1999 (64 FR 35714). Following the D.C.
Circuit’s decision in American Corn
Growers, EPA revised the RHR and
issued the final BART Guidelines on
July 6, 2005. (70 FR 39104). The revised
RHR and the BART Guidelines were
upheld by the D.C. Circuit in Utility Air
Regulatory Group v. EPA, 471 F.3d 1333
(D.C. Cir. 2006).18 As explained in our
proposal and elsewhere in this
document, the BART Guidelines
provide detailed instructions to states
on how to determine which sources are
subject to BART and how to analyze the
five statutory factors in order to set
emissions limits representing BART for
each subject-to-BART source.19 In 2006,
responding to specific questions from
various states and Regional Planning
Organizations (RPOs), EPA issued
18 In response to another D.C. Circuit decision,
Center for Energy and Economic Development v.
EPA, 398 F.3d 653 (D.C. Cir. 2005), EPA revised the
RHR’s provisions governing alternatives to sourcespecific BART determinations on October 13, 2006.
These revisions did not alter the requirements for
source-specific BART determinations that apply to
Wyoming’s BART determinations at issue here.
19 40 CFR Part 51, Appendix Y. While the
Guidelines are only mandatory for fossil fuel-fired
electric generating plants with a total generating
capacity in excess of 750 megawatts, States are
encouraged to follow the BART Guidelines in
making BART determinations for other types of
sources. Id. section I.H. The Guidelines also set
specific presumptive limits for SO2 and NOX for
these large power plants, but allow states to apply
more or less stringent limits based upon sourcespecific five-factor analyses. 70 FR 39131–39132.
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further guidance to help states
implement the RHR and BART
Guidelines.20
As noted in prior responses, EPA
issued a finding of failure to submit for
regional haze SIPs on January 15, 2009
(74 FR 2392), triggering a FIP clock
under CAA section 110(c). By this time,
states already had more than three years
since issuance of the final BART
Guidelines to develop their regional
haze SIPs. By the time the FIP clock
actually ran out in January 2011, EPA
had received regional haze SIPs from
nearly every state. EPA has since
proposed and approved, in part or in
whole, the vast majority of these
SIPs.21 22 This stands in contrast to the
situation in EME Homer City, where the
court noted that, ‘‘every Transport Rule
State that submitted a good neighbor SIP
for the 2006 24-hour PM2.5 NAAQS was
disapproved.’’ Thus, it is clear that
states had ample opportunity to submit
approvable regional haze SIPs before
EPA was obligated to promulgate
regional haze FIPs under CAA section
110(c).
One commenter also pointed to the
D.C. Circuit’s general statements
concerning state and federal roles under
the CAA and argues that EPA has
exceeded its statutorily mandated role
in proposing to disapprove portions of
Wyoming’s regional haze SIP and
promulgate a FIP. While we agree that
the general principles concerning state
and federal roles under Title I of the
CAA apply to our action here, we do not
agree that our action is inconsistent
with those principles. In this action, we
are fulfilling our statutory duty to
review Wyoming’s regional haze SIP,
including its BART determinations, for
20 Memo from Joseph W. Paise Regarding
Regional Haze Regulations and Guidelines for
BART (July 19, 2006); Additional Regional Haze
Questions (Guidance) (Sept. 27, 2006). In addition,
EPA issued final ‘‘Guidance for Setting Reasonable
Progress Goals Under the Regional Haze Program’’
on June 1, 2007, but this Guidance is not directly
relevant for individual BART determinations.
21 See, e.g., 76 FR 36450 (Nevada); 77 FR 24794
(New York); 76 FR 13944 (California); 77 FR 11798
(Rhode Island); 76 FR 27973 (Delaware); 77 FR
12770 (Nebraska); 77 FR 18052 (Colorado); 76 FR
16168 (Oklahoma); 77 FR 11914 (Vermont); 77 FR
11928 (Wisconsin); 76 FR 52604 (Kansas); 76 FR
64186 (Arkansas); 77 FR 11839 (Maryland); 76 FR
58570 (North Dakota); 77 FR 3966 (Illinois); 76 FR
76646 (South Dakota). EPA proposed limited
approval and limited disapproval of the Regional
Haze SIPs of states covered by the Clean Air
Interstate Rule (CAIR), due to the remand of CAIR
by the D.C. Circuit. See, e.g. 77 FR 3691 (Jan. 25,
2012) (proposing limited approval and limited
disapproval of Virginia’s Regional Haze SIP).
22 See, e.g., 76 FR 34608 (California); 76 FR 42557
(Delaware); 76 FR 80754 (Kansas); 77 FR 19 (New
Jersey); 77 FR 5191 (District of Columbia); 77 FR
14604 (Arkansas); 77 FR 17334 (Nevada); 77 FR
24845 (South Dakota); 77 FR 40150 (Nebraska); 77
FR 51915 (New York).
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compliance with the applicable
requirements of the CAA and the RHR,
and to disapprove any portions of the
plan that do not meet those
requirements. Based on our review of
the SIP, we proposed to determine that
certain elements of Wyoming’s regional
haze SIP did meet the requirements of
the CAA and the RHR, and we proposed
to approve those elements. However, for
the reasons explained in detail in our
proposed notices and elsewhere in this
document, we have concluded that five
of Wyoming’s BART determinations 23
and four elements of the regional haze
SIP 24 did not comply with the
requirements of the CAA and the RHR.
Based on these findings, we are required
to disapprove these portions of
Wyoming’s regional haze SIP. As
discussed in detail in several below
responses, the CAA provides EPA with
the authority to review and reject an
inadequate regional haze SIP. Oklahoma
v. EPA, 723 F.3d 1201, 1207 (10th Cir.
2013).
Comment: One commenter stated that
the limits on EPA’s authority to reject a
SIP were affirmed by the Fifth Circuit in
Texas v. EPA, 690 F.3d 670 (5th Cir.
2012), vacating EPA’s rejection of a
Texas SIP revision implementing its
minor new source review program (i.e.,
the Texas Flexible Permit Program). In
the Texas decision, the court reaffirmed
the principle that if a SIP or SIP revision
meets the statutory criteria of the CAA,
then EPA must approve it. The
Wyoming regional haze SIP meets the
statutory criteria of the CAA. Therefore,
EPA’s disapproval of the Wyoming
regional haze SIP exceeds EPA’s
statutory authority.
Response: In Texas, the Fifth Circuit
found that EPA had failed to tie its
disapproval to any specific requirement
in the CAA or EPA’s implementing
regulations.25 In this action, our
disapproval is based explicitly and
squarely on the SIP’s failure to comply
with the CAA section 169A(b)(2)(A), as
implemented through the RHR and the
23 As presented elsewhere in this final notice and
in the docket, the five NOX BART determinations
we are disapproving are for the following:
PacifiCorp Dave Johnston Unit 3, PacifiCorp
Wyodak Unit 1, and Basin Electric Laramie River
Units 1, 2, and 3.
24 As presented elsewhere in this final notice and
in the docket, the four elements of the State SIP we
are disapproving include: (1) Wyoming’s RPGs; (2)
The State’s monitoring, recordkeeping, and
reporting requirements in Chapter 6.4 of the SIP; (3)
portions of the State’s long term strategy (LTS) that
rely on or reflect other aspects of the regional haze
SIP that we are disapproving; and (4) the provisions
necessary to meet the requirements for the
coordination of the review of the reasonably
attributable visibility impairment (RAVI) and the
regional haze LTS.
25 690 F.3d at 679, 682, 686.
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BART Guidelines. Just because a court
found EPA’s disapproval invalid in one
case does not mean that finding applies
in all cases. This situation involves a
very different program under the CAA
and a very different state submittal and
review. The Texas case does not involve
BART or the CAA’s regional haze
provisions at all. Rather, it involved
EPA’s disapproval of SIP revisions
involving Texas’s minor new source
review program. There are a limited
number of specific requirements in EPA
rules for minor source review programs.
In contrast, regional haze SIPs and
BART determinations are subject to the
detailed requirements set forth in CAA
section 169A, the RHR, and the BART
Guidelines.
Comment: One commenter stated that
the CSAPR decision criticized the
CSAPR’s FIP-first approach because it
forces states to ‘‘take a stab in the dark’’
on their compliance obligations only to
be judged later whether they hit the
mark. As the D.C. Circuit explained in
the CSAPR decision, a ‘‘SIP logically
cannot be deemed to lack a required
submission or deemed to be deficient
for failure to meet . . . [an] obligation
before EPA quantifies the . . .
obligation.’’ EME Homer City
Generation, L.P. v. EPA., 696 F.3d 7, 49
(D.C. Cir. 2012), cert. granted 570 U.S.
(June 24, 2013) (No. 12–1182)
(hereinafter ‘‘CSPAR Decision’’).
Other commenters reject this
assertion, explaining that Wyoming was
not forced to take a ‘‘stab in the dark’’
in developing its regional haze SIP. In
EME Homer City, the D.C. Circuit
accepted the state petitioners’ argument
that they had no obligation to submit
SIPs until after EPA defined each state‘s
contribution to interstate pollution and
the necessary emissions reductions to
address that contribution. EME Homer
City, 2012 WL 3570721, at *18
(‘‘[L]ogically, a SIP cannot be deemed to
lack a required submission . . . until
after EPA has defined the State‘s good
neighbor obligation.’’; ‘‘There is no way
for an upwind State to know its
obligation . . . until EPA defines it.’’).
Response: We do not agree that
Wyoming was forced to take a ‘‘stab in
the dark’’ in developing its regional
haze SIP. The regional haze program
and the interstate transport obligations
under the CAA are quite different. The
states’ regional haze obligations have
been clearly defined. EPA issued BART
Guidelines establishing detailed
parameters for state BART
determinations in 2005. Commenter’s
charge that EPA may never issue a FIP
in such circumstances is incorrect. We
explain in detail above how the CAA’s
visibility provisions and EPA’s
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implementing regulations differ from
the good-neighbor provision at issue in
EME Homer City. Wyoming was well
aware of these requirements as it
developed its regional haze SIP, through
EPA comment letters and meetings
between EPA and the State. Finally,
unlike the petitioners in EME Homer
City, none of the commenters here
dispute that Wyoming’s regional haze
SIP and BART determinations were
‘‘required submission[s].’’
Comment: One commenter stated that
the CSAPR decision also made clear that
any FIP issued by EPA must be related
to the ‘‘end goal of the statute.’’ The D.C.
Circuit stated in the CSAPR decision:
‘‘[T]he end goal of the statute is
attainment in the downwind state.
EPA’s authority to force reductions on
upwind states ends at the point where
the affected downwind State achieves
attainment.’’ CSAPR Decision at p. 25.
The ‘‘end goal’’ of the regional haze
statutory requirements is to gradually
achieve ‘‘natural visibility’’ conditions
by the year 2064 under an emission
reduction approach known as
reasonable progress as determined by
the states. EPA’s rush in the proposed
Wyoming FIP to front-load as many
emission reductions as possible in the
first five years of this decades-long
program is a clear indication that EPA
has lost sight of the ‘‘end goal’’ of the
regional haze program. Likewise, EPA’s
failure to account for, and properly
address, other causes of visibility
impairment in its FIP, such as natural
causes (forest fires), out of state sources,
oil and gas sources, etc., demonstrates
that EPA has lost focus on the ‘‘end
goal’’ of the regional haze program.
EPA’s proposed Wyoming FIP violates
this ‘‘end goal’’ principle espoused by
the CSAPR decision.
Response: EPA is required to evaluate
BART factors included in state SIPs
(e.g., ultimately rejecting
methodological flaws and data flaws in
estimating costs of compliance and
visibility, as we have done in this final
action), where the flaws in the analysis
prevented the State of Wyoming from
conducting meaningful consideration of
the BART factors, as required by the
BART Guidelines, and moored to the
CAA’s BART and SIP provisions. North
Dakota v. EPA, 730 F.3d 750, 761 (8th
Cir. 2013).
Furthermore, we do not agree that one
provision of the CAA should be read
and applied in isolation. The
commenter’s position would ignore the
rest of the CAA’s statutory requirements
and violate the ‘‘fundamental canon of
statutory construction that the words of
a statute must be read in their context
and with a view to their place in the
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5055
overall statutory scheme.’’ A court must
therefore interpret the statute ‘‘as a
symmetrical and coherent regulatory
scheme,’’ and ‘‘fit, if possible, all parts
into an harmonious whole.’’ FDA v.
Brown & Williamson Tobacco Corp., 529
U.S. 120, 133 (2000) (quoting Davis v.
Michigan Depart of Treasury, 489 U.S.
803, 809 (1989); Gustafson v. Alloyd
Co., 513 U.S. 561, 569 (1995); and FTC
v. Mandel Brothers, Inc., 359 U.S. 385,
389 (1959)). The commenter’s claim that
one provision in the CAA overrides all
other statutory provisions is unfounded
and not supported by the CAA. In
particular, the statutory requirements
for BART are separate and distinct from
the statutory requirements for
reasonable progress.
Moreover, as explained elsewhere in
this document, EPA’s action fully
accounts for other causes of visibility
impairment. With respect to wildfires,
we explain in detail elsewhere in this
document the role that fires play in
determining natural background
conditions. With respect to oil and gas
sources, we are approving the State’s
determination to not impose controls on
this source category during this
planning period, in part because the
State already applies minor source
BACT to many of them through the
State’s SIP-approved minor NSR
program, and in part because controls
on these sources are not so cost-effective
that we are prepared to say the State
was unreasonable. With respect to
accounting for out-of-state sources, we
cited sources outside the Western
Regional Air Partnership (WRAP)
domain as one factor that made it
reasonable for our RPGs to fall short of
the uniform rate of progress (URP) and
unreasonable to achieve the URP.
Finally, we note that we are approving
some of Wyoming’s BART
determinations and all of Wyoming’s
reasonable progress determinations.
Additionally, BART is required in the
first planning period, which ends in
2018, and is required to be installed as
expeditiously as practicable, but in no
event later than five years after the
effective date of this final notice. In light
of the fact that many of Wyoming’s
Class I areas are not even expected to
meet the URP this planning period, the
notion that EPA has required ‘‘frontloading’’ of controls is utterly without
merit.
Comment: Some commenters stated
that the CSAPR decision considered,
and then rejected, a ‘‘reasonableness’’
standard put forth by EPA as the only
limit on its authority to impose
emission reductions under the CSAPR.
CSAPR Decision at p. 37, ftnt. 23. EPA
likewise purports to impose a
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reasonableness standard as adequate
justification for rejecting the Wyoming
regional haze SIP and imposing a FIP.
The CSAPR decision makes clear that
such a reasonableness standard, not
included in the CAA itself, does not
have a place in justifying EPA’s actions
in issuing a FIP. For this added reason,
the CSAPR decision makes clear the FIP
exceeds EPA’s statutory authority.
Response: EPA disagrees with this
comment. First, the commenters
misunderstand the cited footnote in the
CSAPR decision. In the D.C. Circuit’s
view, EPA ignored statutory limits on its
authority and instead claimed that
reasonableness was the only bound on
EPA’s authority. Here, EPA makes no
such claim. EPA, of course, has the
authority and the duty to review
Wyoming’s SIP for compliance with the
CAA and the RHR.
In reviewing the Wyoming regional
haze SIP, EPA has determined that a
‘‘reasonableness’’ standard is in fact
harmonious with the CAA and the RHR,
and the courts have agreed. Oklahoma
v. EPA, 723 F.3d 1201, 1207 (10th Cir.
2013) (‘‘The EPA therefore had a
reasonable basis for rejecting the 2008
Cost Estimates [that were based on the
overnight costing method] as not
complying with the guidelines.’’); see
also North Dakota v. EPA, 730 F.3d 750,
761 (8th Cir. 2013) (explaining EPA is
not required to ‘‘approve a BART
determination that is based upon an
analysis that is neither reasoned nor
moored to the CAA’s provisions’’).
The CAA requires states to submit
SIPs that contain such measures as may
be necessary to make reasonable
progress toward achieving natural
visibility conditions, including BART.
The CAA accordingly requires the states
to submit a regional haze SIP that
includes BART as one necessary
measure for achieving natural visibility
conditions. See Alaska Dep’t of Envtl.
Conservation v. EPA, 540 U.S. 461, 500
(2004) (in a related context, holding that
EPA validly issued stop work orders
because the state’s BACT determination
‘‘simply did not qualify as reasonable in
light of the statutory guides.’’ (emphasis
added)) (hereinafter ‘‘ADEC’’). Thus we
are not establishing a new
reasonableness standard, as the
commenter asserts.
Comment: In the CSPAR decision, the
D.C. Circuit found it ‘‘inconceivable’’
that Congress would bury in the CAA
‘‘an open-ended authorization for EPA
to effectively force every power plant in
the upwind States to install every
emissions control technology EPA
deems ‘cost effective’.’’ CSAPR Decision
at p. 40. In so finding, the court refused
to transform a ‘‘narrow’’ provision into
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a ‘‘broad and unusual’’ authority that
would overtake other core provisions of
the Act.’’ Id. Similarly, it is
inconceivable in the regional haze
context that Congress would bury an
open-ended authorization allowing EPA
to ignore its own BART Guidelines,
overrun carefully crafted state regional
haze SIPs and BART determinations,
and require the installation of expensive
emission controls which result in
minimal regional haze improvements.
This principle espoused in the CSAPR
decision is particularly applicable in the
regional haze context where, just like in
the CSAPR, EPA’s BART determinations
in the Wyoming FIP are ‘‘not a clear
numerical target—far from it—until EPA
defines the target.’’ CSAPR Decision at
p. 48. And in spite of EPA initially
helping to define ‘‘the target’’ by issuing
its BART Guidelines (which EPA
subsequently ignored), EPA did not
begin to redefine the target until it began
to issue various determinations around
the country in reaction to various state
regional haze SIPs. Even then, EPA’s
‘‘target’’ is not clear and certainly is
impossible to determine, on a state or
source-by-source basis, until EPA sets
the target in a state-specific FIP.
Like the upwind states in the CSAPR
decision, it was ‘‘impossible’’ for
Wyoming to determine its regional haze
obligation ‘‘until EPA defined it.’’ Id.
This process effectively allows EPA to
impose any standard it wants with little
ability for the states (or sources) to
achieve the redefined target through a
state-led process because of the tight
deadlines imposed by EPA as a result of
negotiated consent decree deadlines.
Response: We do not agree that we
have ignored the CAA and BART
Guidelines. As explained in our
proposed notice and elsewhere in this
document, our decisions are firmly
grounded on the CAA provisions and
BART Guidelines, and Wyoming was
well aware of these requirements as it
developed its SIP. In addition, the
comparison of BART determinations
and the CSAPR decision is not
appropriate. In contrast to CSPAR, the
CAA and RHR do not set specific
numerical targets for BART
determinations. Instead, they require
states to reasonably consider the five
statutory factors, which, as we have
detailed in our proposal and in our
response to comments, Wyoming did
not do. Furthermore, EPA provided
extensive comments to the State on the
proposed regional haze SIP and met
with the State on numerous occasions,
so the State was aware of EPA’s
concerns regarding approvability before
the SIP was submitted to EPA. As
explained below in greater detail, the
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Consent Decree that covers this action
has not hindered Wyoming’s ability to
develop and submit an approvable SIP.
Wyoming can submit new SIP revisions,
and request that EPA review and
approve them, to replace the FIP
elements at any time.
To the extent that the comment argues
that the RHR itself is invalid for similar
reasons to those for which the D.C.
Circuit vacated CSAPR, the time to
make those arguments has passed.
Finally, in establishing the BART
requirements, Congress was addressing
a category of large sources that predated the modern NSR affected sources,
which were determined to significantly
contribute to regional haze and set an
expectation that included consideration
of cost, feasibility, and effect on regional
haze (as well as the other five factors)
for those sources, many of which did
not have modern pollution controls
because of their age and because they
hadn’t been addressed through ozone
SIPs the way so many eastern sources
had. This is one of the reasons why the
western regional haze SIPs are seeing
emission controls.
Comment: One of the commenters
stated that one of the key conclusions of
the CSAPR decision was that EPA
exceeded the scope of its authority by
requiring emission reductions beyond
the statutory or regulatory requirements.
In the CSAPR decision, the court looked
at the fact that once EPA had
determined that an upwind emission
source contributed ‘‘significantly’’ to
nonattainment or maintenance of the
standard in a downwind state; it was
‘‘in’’ for purposes of requiring emission
reductions. The emission reduction
requirements were then based on costeffectiveness thresholds that were
applied uniformly throughout the
CSAPR region. In other words, all
emissions that could be reduced, for
example, for a cost between $1 and $500
per ton were effectively required. The
court held that this approach resulted in
a situation where some sources had to
bear a disproportionate amount of costs,
based on their relative contribution to
the nonattainment or maintenance
problem.
Similarly in the regional haze context,
EPA established an ‘‘in or out’’ criteria
of a 0.5 deciview impact. Sources with
modeling results that suggested the
impact was greater than 0.5 were ‘‘in’’
and required further analysis. If, under
EPA’s FIP approach, the facilities could
cost-effectively (as determined by EPA,
not the states) control emissions, they
were required to do so. Oftentimes, EPA
has required the controls
notwithstanding the negligible
contribution the emission reductions
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will have towards meeting the
requirement of the RHR. EPA’s
conclusions requiring individual
sources to reduce emissions under its
subjective cost-effectiveness criteria
have no relationship to visibility
impacts or improvements, and EPA
failing to conduct that modeling, but
supporting a determination of
reasonableness of controls ‘‘based on the
high cost effectiveness at each of the
units.’’ 77 FR at 33034, 33038 and
33055.
EPA’s conclusions regarding emission
reductions that are based on the costeffectiveness of controls without an
appropriate linkage to visibility
improvement and meeting the goals and
objectives of the RHR exceed EPA’s
statutory authority as suggested by the
CSAPR decision.
Response: We agree with some of this
comment and disagree with other
portions. As an initial matter, as we
explained in our proposed notice, we
note that:
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Wyoming used a contribution threshold of
0.5 deciviews for determining which sources
are subject-to-BART. By using a contribution
threshold of 0.5 deciviews, Wyoming
exempted seven of the fourteen BARTeligible sources in the State from further
review under the BART requirements. Based
on the modeling results, the State determined
that P4 Production, FMC Granger, and OCI
Wyoming had an impact of .07 deciview,
0.39 deciview, and 0.07 deciview,
respectively, at Bridger Wilderness. Black
Hills Neil Simpson 1, Sinclair Casper
Refinery, and Sinclair—Sinclair Refinery
have an impact of 0.27 deciview, 0.06
deciview, and 0.12 deciview, respectively, at
Wind Cave. Dyno-Nobel had an impact of
0.22 deciview at Rocky Mountain National
Park. These sources’ modeled visibility
impacts fell below the State’s threshold of 0.5
deciview and were determined not to be
subject-to-BART. 78 FR 34747
Since the State’s approach is consistent
with the BART Guidelines 26 and given
the relatively limited impact on
visibility from these seven sources, as
explained earlier in this document and
in our proposals, we are finalizing our
proposal to approve Wyoming’s
threshold of 0.5 deciviews as reasonable
for determining whether its BARTeligible sources are subject-to-BART. 78
FR 34734, 34747
We do not agree that our decision
exceeds our statutory authority and the
goals and objectives of the RHR. CAA
section 110(a)(2)(J) requires each plan
submitted by a state to ‘‘meet the
applicable requirements’’ of Part C of
Title I of the CAA, including those for
‘‘visibility protection.’’ In the case of a
regional haze SIP submittal, the
26 40
CFR part 51, appendix Y, section III.A.1.
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‘‘applicable requirements’’ include the
requirement that each source found
subject-to-BART, ‘‘procure, install, and
operate, as expeditiously as practicable
(and maintain thereafter) the best
available retrofit technology . . .’’ 27
Section 169A(g)(2) further provides that:
In determining best available retrofit
technology the State (or the Administrator in
determining emission limitations which
reflect such technology) shall take into
consideration the costs of compliance, the
energy and non-air quality environmental
impacts of compliance, any existing
pollution control technology in use at the
source, the remaining useful life of the
source, and the degree of improvement in
visibility which may reasonably be
anticipated to result from the use of such
technology.28
Similarly, the RHR provides that:
The determination of BART must be based
on an analysis of the best system of
continuous emission control technology
available and associated emission reductions
achievable for each BART-eligible source that
is subject to BART within the State. In this
analysis, the State must take into
consideration the technology available, the
costs of compliance, the energy and non-air
quality environmental impacts of
compliance, any pollution control equipment
in use at the source, the remaining useful life
of the source, and the degree of improvement
in visibility which may reasonably be
anticipated to result from the use of such
technology.29
Wyoming’s BART determinations for
NOX at five BART units fall short of
these requirements in several respects.
First, Wyoming did not analyze the
‘‘best system of continuous emission
control technology available and
associated emission reductions
achievable.’’ This is explained in detail
in our proposed rulemaking, the docket
for this action, and elsewhere in this
document. Therefore, Wyoming has not
demonstrated that its BART
determinations were ‘‘based on an
analysis of the best system of
continuous emission control technology
available and associated emission
reductions achievable.’’
For example, as we explained in our
proposed notices and elsewhere in this
final action, Wyoming did not
appropriately consider the ‘‘degree of
improvement in visibility which may
reasonably be anticipated’’ from
installation of BART because it did not
provide visibility improvement
modeling from which the benefits of
individual NOX controls could be
ascertained. Thus Wyoming’s BART
27 CAA section 169A(b)(2)(A), 42 U.S.C.
7491(b)(2)(A).
28 42 U.S.C. 7491(g)(2).
29 40 CFR 51.308(e)(1)(ii)(A).
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determinations for NOX do not meet the
requirements of CAA section 169A(g)(2)
or 40 CFR 51.308(e)(1)(ii)(A).
Additionally, as explained in our
proposed notices and elsewhere in the
modeling section of this final action, it
was not possible to ascertain the
visibility improvement from the NOX
control options as the State modeled
emission reductions for multiple
pollutants together. For this reason, in
the modeling conducted by EPA, we
held SO2 and PM emission rates
constant (reflecting the ‘‘committed
controls’’ for those pollutants identified
by Wyoming), and varied only the NOX
emission rate. This allowed us to isolate
the degree of visibility improvement
attributable to the NOX control option.
In addition, 40 CFR 51.308(e)(1)(ii)(B)
provides that the determination of
BART for fossil-fuel fired power plants
having a total generating capacity
greater than 750 megawatts must be
made pursuant to the guidelines in
appendix Y of part 51 (Guidelines for
BART Determinations under the
Regional Haze Rule).
All of the Wyoming BART sources,
except Wyodak, each have a generating
capacity greater than 750 megawatts.
Therefore, the BART determinations for
these BART sources must be made
pursuant to the BART Guidelines.
However, Wyoming’s BART
determinations for these sources did not
fully comply with the BART Guidelines.
In particular, as explained more fully
elsewhere in this document, contrary to
the Guidelines’ admonition that ‘‘cost
estimates should be based on the CCM,
where possible,’’ the control cost
calculations supplied by the utilities
and relied upon by Wyoming included
costs not allowed by the CCM, such as
owner’s costs and Allowance for Funds
Utilized During Construction (AFUDC).
Thus, Wyoming’s consideration of the
‘‘cost of compliance’’ for these units was
not consistent with the Guidelines.
Furthermore, as explained elsewhere in
this document, Wyoming’s
consideration of visibility benefits was
inconsistent with the Guidelines
because the State did not provide
visibility modeling from which the
visibility improvement from individual
controls could be ascertained. Finally,
for all pollutants at all units covered by
today’s action, Wyoming’s regional haze
SIP does not meet the requirements of
40 CFR 51.308(e)(1)(iv) and (v) because
it lacks the following elements:
• A requirement that each source
subject to BART be required to install
and operate BART as expeditiously as
practicable, but in no event later than 5
years after approval of the
implementation plan revision.
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• A requirement that each source
subject to BART maintain the control
equipment required by this subpart and
establish procedures to ensure such
equipment is properly operated and
maintained.
These two requirements are
mandatory elements of the RHR and are
necessary to ensure that BART is
procured, installed, and operated as
expeditiously as practicable and
maintained thereafter, as required under
CAA section 169A(b)(2)(A).
Moreover, the CAA and regional haze
rule require that SIPs contain provisions
that make emissions limits, including
BART limits, practically enforceable.
CAA section 110(a)(2)(A)–(B) require
that emissions limits such as BART be
‘‘practically enforceable’’ and SIPs
provide for establishment, methods and
procedures necessary to monitor,
compile, and analyze data. CAA section
302(k) requires emissions limits to be
met on a continuous basis. Additionally,
CAA section 169A(b)(2) requires that
regional haze SIPs include ‘‘such
emission limits, schedules of
compliance and other reasonable
measures’’ necessary to meet the goals
of the regional haze program.’’ As
discussed in our proposed notices and
elsewhere in this final notice,
Wyoming’s regional haze SIP lacks
requirements for monitoring,
recordkeeping, and reporting sufficient
to ensure that the BART limits are
enforceable and are met on a continuous
basis.
Therefore, Wyoming’s BART
determinations for these five units
covered by the FIP do not meet the
BART requirements of the CAA, the
RHR and the BART Guidelines.
Additionally, Wyoming’s SIP
requirements do not ensure the BART
limits are enforceable for all BART
sources for which there is a SIP or FIP
emissions limit, and therefore do not
meet the requirements of the CAA and
RHR. Accordingly, we are compelled to
partially approve and partially
disapprove Wyoming’s regional haze
SIP.
Comment: EPA cannot invoke its
Section 110 SIP approval authority as
grounds for rejecting state BART
determinations with which it disagrees.
The CAA does not require any specific
degree of visibility improvement in the
determination and only requires BART
for the purpose of eliminating or
reducing impairment to visibility. See
CAA Section 169A, 42 U.S.C. 7491.
Consistent with the long-recognized
principle that EPA may not ‘‘condition
approval of the plan of any State, on the
State’s adoption of a specific control
measure,’’ Virginia, 108 F.3d at 1408,
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EPA has no statutory authority to
disapprove a SIP that contains a BART
determination for an individual facility
that complies with the statutory BART
factors. Any other result would allow
EPA to employ its generalized SIP
approval authority to ‘‘run roughshod
over the procedural prerogatives that the
Act has reserved to the States.’’
Bethlehem Steel Corp., 742 F.2d at 1036.
The fact that states must propose SIP
revisions ‘‘as may be necessary’’ to
achieve reasonable progress does not
mean EPA has authority to countermand
the textual commitment of specific
BART decisions to the states. The D.C.
Circuit interpreted similar language in
Section 110(k)(5) to constrain EPA’s
authority over SIP approval and
disapproval. See Virginia, 108 F.3d at
1409. The SIP call provisions of Section
110(k)(5) state that when a SIP is
inadequate ‘‘the Administrator shall
require the State to revise the plan as
necessary to correct such inadequacies.’’
But the Virginia court rejected the
agency’s expansive view of this phrase
as authority to impose specific control
measures for specific emission sources.
Response: States are required by the
CAA to address the BART requirements
in their SIP. Our disapproval of the NOX
BART determinations in the Wyoming
regional haze SIP is authorized under
the CAA because the State’s NOX BART
determinations for the five units do not
satisfy the statutory criteria. The State’s
analysis of the cost effectiveness of
controls and visibility analyses were
flawed due to reasons discussed
elsewhere in the proposed and final
notices. While states have authority to
exercise different choices in
determining BART, the determinations
must be reasonably supported.
Wyoming’s errors in taking into
consideration the costs of compliance
were significant enough that we cannot
conclude the State determined BART
according to CAA standards. The cases
cited by the commenters stress
important limits on EPA authority in
reviewing SIP submissions, but our
disapproval of these NOX BART
determinations for the five units has an
appropriate basis in our CAA authority.
We did not require Wyoming to adopt
specific control measures for specific
emission sources. Instead, we
disapproved some of Wyoming’s BART
determinations for reasons described in
detail in our proposal and elsewhere in
our response to comments. To
promulgate our FIP, EPA then had both
the authority and the duty to determine
specific control measures for specific
sources.
Finally, contrary to the commenter’s
assertion, the Bethlehem Steel case is
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inapplicable here. We are promulgating
BART emission limitations and other
FIP elements described elsewhere in
this document under the authority of
CAA section 110(c), not through our
action on Wyoming’s SIP. We have
authority to promulgate our FIP under
110(c) on two separate grounds: first,
based on our January 2009 finding of
failure to submit the regional haze plan
elements required by 40 CFR 51.309(g),
the reasonable progress requirements for
areas other than the 16 Class I areas
covered by the Grand Canyon Visibility
Transport Commission Report; and
second, based on our partial disapproval
of the regional haze SIP.
Comment: We received comments
that EPA does not have the authority
under the CAA to issue a regional haze
FIP in this instance. Commenters
contend that EPA’s role under Section
110 in reviewing states’ regional haze
SIPs is narrow and that the CAA
confines EPA to the ministerial function
of reviewing SIPs for consistency with
the CAA’s requirements. Commenters
assert that Wyoming submitted a
regional haze SIP that met the
requirements of Section 51.309 and
included all the required elements and
that EPA admits that Wyoming has
considered all five BART factors.
Therefore, commenters go on to say that
EPA’s sole function was to review
whether Wyoming followed the regional
haze requirements, including Appendix
Y, in preparing the Wyoming regional
haze SIP, and Congress did not
authorize EPA to ‘‘second guess’’
Wyoming’s BART decision making, or
to substitute its own judgment, simply
because EPA would prefer different
BART and reasonable progress NOX
controls. Commenters go on to point out
that courts have consistently held that
states are primarily responsible for SIP
development; EPA’s role is ministerial.
Commenters cite that the Supreme
Court has recognized the states’ primary
role in developing SIPs, holding ‘‘so
long as the ultimate effect of a State’s
choice of emission limitations is in
compliance with the national standards
for ambient air, the State is at liberty to
adopt whatever mix of emission
limitations it deems best suited to its
particular situation.’’ Train v. NRDC,
421 U.S. 60, 79 (1975). Commenters
argue that EPA is going beyond its
ministerial function of reviewing
Wyoming’s regional haze SIP for
consistency with the CAA’s
requirements; it is attempting to design
Wyoming’s SIP by establishing new
NOX emission limits, contrary to its
promulgated BART regulations.
Commenters go on to say that EPA
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should follow the structure of the CAA
and give deference to the State’s
judgment in determining BART in
Wyoming’s regional haze SIP.
Response: States are required by the
CAA to address the BART requirements
in their SIP. Our disapproval of the NOX
BART determinations in the Wyoming
regional haze SIP is authorized under
the CAA because the State’s NOX BART
determinations for the five units do not
satisfy the statutory criteria. The State’s
analyses of the cost effectiveness of
controls and visibility analyses were
flawed due to reasons discussed in the
introduction and BART sections of this
document. While states have the
authority to exercise different choices in
determining BART, the determinations
must be reasonably supported.
Wyoming’s errors in taking into
consideration the costs of compliance
and visibility analyses were significant
enough that we cannot conclude the
State determined BART according to
CAA standards. The cases cited by the
commenters stress important limits on
EPA authority in reviewing SIP
submissions, but our disapproval of
these NOX BART determinations for the
five units has an appropriate basis in
our CAA authority.
Comment: Under the CAA, both the
federal government and the states have
responsibilities for maintaining and
improving air quality. The federal
government has the authority to set
specific emissions targets, but the states
have the authority to develop and
impose their own regulatory structure to
meet those. As long as the State meets
its specific criteria, which Wyoming can
and will show that it has done, the fact
that EPA does not share the State’s
opinion regarding the best course of
action is immaterial.
This reading of the CAA is the
opinion of the Congress that passed the
regional haze program in 1977.
Committee and floor debate in Congress
at the time makes clear that Congress
fully intended for the states to possess
a high degree of primacy in regional
haze decisions. The primary sponsor of
the CAA and 1977 amendments in the
Senate was the late Senator Edmund
Muskie, a Democrat from Maine. In his
opening address to the Senate on the
Conference Report to the 1977
amendments, Senator Muskie said,
‘‘under this legislation, the
administrator of the EPA will be more
reliant on local and state capabilities to
create the institutional and
infrastructural changes necessary to
achieve clean air. And perhaps this is as
it should be. We have learned that there
is little political support for inartfully
conceived national measures. We have
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learned that where change can be made,
it must be made with the full
understanding and support of the
people who are affected by that
change.’’
While the courts in some instances
may not give adequate weight to the
intent of Congress in drafting
legislation, Congress’s intent in passing
the nation’s law is something that
Congress itself takes very seriously.
Some courts have honored
Congressional intent and upheld the
CAA as a cooperative statute. In
Appalachia Power Company v. EPA
[sic], the courts determined that the
CAA includes a cooperative standard
they call a federalism bar. In Train and
Luminant Generation Co., LLC v. EPA,
675 F.3d 917 (5th Cir. 2012) (hereinafter
‘‘Luminant’’), the courts held that the
EPA had no authority to overturn the
decisions of the states so long as the
basic requirements of Section 110 are
met.
EPA does not have the authority
under the CAA to issue a regional haze
FIP in this instance. EPA contends its
review of the Wyoming SIP is ‘‘pursuant
to section 110 of the CAA.’’ 78 FR
34738. Section 110(a)(2) provides the
general requirements that a SIP must
contain. Importantly, EPA’s role under
Section 110 in reviewing states’ regional
haze SIPs is narrow: ‘‘With regard to
implementation, the (CAA) confines the
EPA to the ministerial function of
reviewing SIPs for consistency with the
(CAA)’s requirements.’’ Luminant
Generation Co., LLC v. EPA, 675 F.3d
917, 921 (5th Cir. 2012) (citing section
110(k)(3)). As the court in Luminant
explained, if the state’s submissions
‘‘satisfy those basic requirements (found
in section 110), the EPA must approve
them,’’ and ‘‘(t)hat is the full extent of
the EPA’s authority in the SIP-approval
process because that is all the authority
that the CAA confers.’’ Id. at 932. Here,
Wyoming submitted a regional haze SIP
that met the requirements of Section 309
and included all the required elements.
The Wyoming SIP submittals are well
developed and comprehensive. EPA
admits that Wyoming considered all five
BART factors. 78 FR 34748. Therefore,
EPA’s role was to review whether
Wyoming followed the regional haze
requirements, including Appendix Y,
and provided factual support for the
Wyoming regional haze SIP. Congress
did not authorize EPA to ‘‘second
guess’’ Wyoming’s BART decision
making, or to substitute its own
judgment, simply because EPA would
prefer different BART and reasonable
progress NOX controls.
More recently, the D.C. Court vacated
the CSAPR. The court’s 2012 opinion in
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the CSAPR case is illustrative for our
purposes because the EPA used very
similar arguments to justify their
authority in CSAPR as they’re using
today for regional haze. In vacating the
CSAPR rule, the D.C. Circuit Court
writes ‘‘under the CAA, the federal
government sets air quality standards,
but states retain the primary
responsibility for choosing how to attain
those standards within their borders.
The Act thus leaves it to the individual
states to determine, in the first instance,
the particular restrictions that will be
imposed on particular emitters within
their borders.’’ The court goes on to
write that ‘‘. . .the statutory federalism
bar prohibits the EPA from using the SIP
process to force states to adopt specific
control measures.’’
Response: We responded to similar
comments above.30 With respect to
EPA’s supposed admission that
Wyoming considered the five BART
factors, the precise language in the
proposal notice is: ‘‘We find that
Wyoming considered all five steps
above in its BART determinations, but
we propose to find that its consideration
of the costs of compliance and visibility
improvement for the EGUs was
inadequate and did not properly follow
the requirements in the BART
Guidelines and statutory requirements,
as explained below.’’ 78 FR 34748. With
respect to the legislative history quoted,
the comment does not provide any
connection between the general remarks
of Senator Muskie regarding the 1977
Amendments and EPA’s interpretation
of the visibility provisions in the Act.
Comment: We received numerous
general comments that EPA has
overstepped its authority and that states
have the responsibility of determining
what controls are necessary for regional
haze.
Response: As explained earlier, the
states have the responsibility to draft the
regional haze SIP and EPA has the
responsibility of ensuring state plans,
including regional haze SIPs, conform to
the CAA. As the drafter of the regional
haze SIP, the State generally has the
authority to decide how each of the
BART factors are taken into account and
weighed. EPA is not disapproving
Wyoming’s BART determinations
because we disagree with how Wyoming
weighed the relevant factors, such as the
cost of controls or the degree of
visibility improvement resulting from
30 As the commenter mentions, we agree that we
did approve Wyoming’s regional haze SIP
submitted under Section 309 of the RHR (40 CFR
51.309) (77 FR 73926 (Dec. 12, 2012)), as in that
action we determined the State met the
requirements of 40 CFR 51.309 and related
provisions.
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the use of controls. EPA is disapproving
certain Wyoming BART determinations
because the State did not consider these
factors in its BART determinations in
accordance with the RHR and the Act.
Comment: EPA’s regional haze FIP
failed to afford the required deference to
the technical, policy and other
discretion granted to Wyoming under
the CAA and regional haze program.
Congress added section 169A to the
CAA in order to address the
‘‘impairment of visibility’’ in Class I
areas that ‘‘results from man-made air
pollution.’’ This provision of the CAA,
in turn, describes separate roles for EPA,
the states, and major sources such as
PacifiCorp’s BART Units.
EPA’s roles are to create a report, see
CAA section 169A(a)(2)–(3), create
regional haze regulations, see CAA
section 169A(a)(4), provide guidelines
for the states, see CAA section
169A(b)(1), and determine whether
regional haze SIPs submitted by the
states follow the regulations and
guidelines, and contain the required
elements. CAA section 110. The states’
roles, which are central to the regional
haze program, are intended to be
accomplished using substantial
discretion which, in turn, requires
significant deference from EPA. States
are required to submit a regional haze
SIP that contains ‘‘emission limits,
schedules of compliance and other
measures as may be necessary to make
reasonable progress toward meeting the
national goal.’’ CAA section 169A(b)(2).
States also must ‘‘determine[*thnsp;]’’
BART for ‘‘each major stationary
source.’’ CAA 169A(b)(2)(A). BART
sources, such as PacifiCorp’s BART
units, are required to ‘‘procure, install,
and operate (BART) as expeditiously as
practicable.’’ CAA section
169A(b)(2)(A).
Thus, the CAA mandates that states
have the primary role in developing
regional haze SIPs to protect visibility in
Class I areas. Likewise, the RHR makes
clear that states have the responsibility
to create and implement regional haze
SIPs. In contrast, EPA’s role is to
develop ‘‘guidelines’’ for the states to
use in implementing regional haze SIPs
and to determine whether states
followed those guidelines. CAA section
169A(b)(1). In short, the CAA
anticipates that states, using their
discretion, develop regional haze SIPs
using EPA guidelines. This is exactly
what Wyoming did in issuing BART
permits and developing the Wyoming
regional haze SIP.
In issuing regional haze guidelines,
EPA recognized the broad discretion
granted to the states by the CAA.
Specifically, EPA adopted guidance to
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address BART determinations for
certain large electrical generating
facilities, referred to as ‘‘Appendix Y.’’
EPA created further guidance in the
Federal Register responding to
comments concerning the thenproposed Appendix Y, referred to as the
‘‘Preamble.’’ EPA recognized in the
Preamble that ‘‘how states make BART
determinations or how they determine
which sources are subject to BART’’ are
among the issues ‘‘where the Act and
legislative history indicate that Congress
evinced a special concern with insuring
that states would be the decision
makers.’’ 70 FR 39104, 39137 (July 6,
2005).
Likewise, in analyzing the
applicability of certain executive orders,
EPA stated that ‘‘ultimately states will
determine the sources subject to BART
and the appropriate level of control for
such sources’’ and that ‘‘states will
accordingly exercise substantial
intervening discretion in implementing
the final rule.’’ Id. at 39155. The U.S.
Court of Appeals for the D.C. Circuit has
affirmed that EPA’s role regarding
regional haze programs is limited and
that a state’s role is paramount. Indeed,
the Court found that the CAA ‘‘calls for
states to play the lead role in designing
and implementing regional haze
programs.’’ American Corn Growers
Ass’n v. E.P.A., 291 F.3d 1, 2 (D.C. Cir.
2002). The court also reversed a portion
of EPA’s original RHR because it found
that EPA’s method of analyzing
visibility improvements distorted the
statutory BART factors and was
‘‘inconsistent with the Act’s provisions
giving the states broad authority over
BART determinations.’’ Id. at 8; (see
also Utility Air Regulatory Group v.
EPA, 471 F.3d 1333, 1336 (D.C. Cir.
2006) (The second step in a BART
determination ‘‘requires states to
determine the particular technology that
an individual source ‘subject to BART’
must install.’’)). The court in American
Corn Growers emphasized that Congress
specifically entrusted states with
making BART five-factor analysis
decisions: ‘‘[t]o treat one of the five
statutory factors in such a dramatically
different fashion distorts the judgment
Congress directed the states to make for
each BART-eligible source.’’ American
Corn Growers, 291 F.3d at 6.
The court in American Corn Growers
also outlined the relevant legislative
history that recounts a specific
agreement reached in Congress which
granted this authority to the states: ‘‘The
‘agreement’ to which the Conference
Report refers was an agreement to reject
the House bill’s provisions giving EPA
the power to determine whether a
source contributes to visibility
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impairment and, if so, what BART
controls should be applied to that
source. Pursuant to the agreement,
language was inserted to make it clear
that the states—not EPA—would make
these BART determinations. The
Conference Report thus confirms that
Congress intended the states to decide
which sources impair visibility and
what BART controls should apply to
those sources. The RHR attempts to
deprive the states of some of this
statutory authority, in contravention of
the Act.’’ Id. at 8. EPA’s FIP action
makes the same mistake and, if
finalized, will be similarly reversible.
In sum, based on the language in the
CAA, the RHR, EPA’s own guidelines,
and case law, the states have significant
discretion when creating regional haze
SIPs.
Response: We responded to similar
comments above and elsewhere in this
document.
Comment: EPA failed to properly
account for that discretion in analyzing
the Wyoming regional haze SIP. EPA
should have acknowledged that the
Wyoming regional haze SIP followed
the law and was supported by the facts.
Examples of EPA ignoring Wyoming’s
discretion include: Visibility
improvement; cost effectiveness
analysis; modeling; application of the
five BART factors; and reasonable
progress analyses.
Response: We responded to similar
comments above and elsewhere in this
document.
Comment: EPA’s proposed action
ignores the congressional commitment
to have local decisions under the CAA—
particularly those relating to BART—
made by the states. States have the
primary responsibility for preventing air
pollution under the CAA. CAA section
101(a)(3), 42 U.S.C. 7401(a)(3). Pursuant
to this principle, states, not EPA, have
always had primary control over
decisions to impose specific emission
limits (and therefore specific pollution
control technologies) for individual
facilities. By congressional design,
under the CAA EPA ‘‘is relegated . . .
to a secondary role in the process of
determining and enforcing the specific,
source-by-source emission limitations
which are necessary [to meet] national
standards.’’ Train v. NRDC, 421 U.S. 60,
79 (1975) (hereinafter ‘‘Train’’). This
basic division of responsibilities
between EPA and the States remained
unchanged when Congress amended the
Act in 1977 and again in 1990. See
Virginia v. EPA, 108 F.3d 1397, 1408–
10 (D.C. Cir. 1997).
Congress took this principle a step
further under the regional haze program,
specifically directing that BART is to be
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‘‘determined by the State.’’ CAA section
169A(b)(2)(A), 42 U.S.C. section
7491(b)(2)(A). Congress adopted the
BART provisions to address visibility,
rather than health concerns. See H.R.
Rep. 95–294, at 529 (1977) (‘‘It should
be made clear at the outset that this
provision [concerning BART] is totally
unrelated to any question involving
public health.’’) (separate views of
Messrs. Devine, Krueger, Broyhill,
Gammage, Clarence J. Brown, Collins,
Moore and Stockman). Congress
therefore sensibly left decisions relating
to the imposition of costly visibility
control technologies on certain existing
sources entirely to the states, where
local factors could be properly
considered and implemented:
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The agreement clarifies that the state,
rather than the Administrator, identifies the
source that impairs visibility in the Federal
class I areas. ‘‘. . . In establishing emission
limitations for any source which impairs
visibility, the State shall determine what
constitutes ‘best available retrofit technology’
. . .’’ H.R. Conf. Rep. 95–564, at 155 (1977).
While the original House bill would have
given EPA the power to determine what
BART controls should be applied to
individual sources, Congress eventually
inserted the current statutory language to
make it clear that the States, rather than EPA,
would make BART determinations. See id.; 5
Leg. History of CAA Amendments 1997 P.L.
95–95, H8663 (1997) (‘‘The provision [in the
original bill] was modified to give States a
greater role in identifying sources which are
contributing (or may in the future contribute)
to visibility problems and in establishing
control requirements for those sources.’’).
Senator Muskie confirmed during the floor
debate that ‘‘the State, not the Administrator,
identifies a source that may impair visibility’’
and that ‘‘it is the State which determines
what constitutes ‘Best Available Retrofit
Technology.’ ’’ 123 Cong. Rec. 26,854 (1977).
The federal courts have enforced this
legislative intent. In American Corn
Growers, the D.C. Circuit quoted at
length from the legislative history of
section 169A to conclude that it was
‘‘clear that the States—not EPA—would
make these BART determinations.’’ 291
F.3d at 8; see also id. at 8 (‘‘The
Conference Report . . . confirms that
Congress intended the States to decide
which sources impair visibility and
what BART controls should apply to
those sources.’’). American Corn
Growers reaffirms that the states have
‘‘broad authority’’ to make their own
BART determinations. Id. It also
reaffirms that EPA cannot ‘‘deprive the
states of some of this statutory
authority,’’ nor can EPA ‘‘constrain[ ]
authority Congress conferred on the
states’’ with respect to BART
determinations. Id. at 8–9. It was for this
reason that the court struck EPA’s first
attempt at the Regional Haze Rule: it
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purported to tell the states how to make
BART determinations. Id. at 6–7. The
same court later reiterated that BART
‘‘requires States to determine the
particular technology that an individual
source ‘subject to BART’ must install.’’
Utility Air Regulatory Grp. v. EPA, 471
F.3d 1333, 1336 (D.C. Cir. 2006).
Other federal courts have recognized
the cooperative federalism policies on
which the CAA in general—and the
regional haze provisions in particular—
are based. See, e.g., Texas v. EPA, 690
F.3d 670, 684 (5th Cir. 2012); Ellis v.
Gallatin Steel Co., 390 F.3d 461, 467
(6th Cir. 2004); Sierra Club v. EPA, 315
F.3d 1295, 1300 (11th Cir. 2002); Am.
Lung Ass’n of N.J. v. Kean, 871 F.2d 319,
322 (3d Cir. 1989). Under cooperative
federalism, states retain the discretion
and flexibility to make their own
choices based on local conditions,
histories, and policies. See, e.g., Budget
Prepay, Inc. v. AT&T Corp., 605 F.3d
273, 281 (5th Cir. 2010) (‘‘ ‘cooperative
federalism’ . . . necessarily implies that
states may reach differing conclusions
on specific issues relating to the
implementation of the [statute]’’); Global
NAPs, Inc. v. Mass. Dep’t of Telecom. &
Energy, 427 F.3d 34, 46 (1st Cir. 2005)
(cooperative federalism has ‘‘the
intended effect of leaving state
commissions free, where warranted, to
reflect the policy choices made by their
states’’ and to implement statutory
provisions ‘‘fairly and with due regard
to . . . local conditions . . . and . . .
historical circumstances’’); Taylor v. Vt.
Dep’t of Educ., 313 F.3d 768, 777 (2d
Cir. 2002) (‘‘‘[c]ooperative federalism
. . . allows some substantive
differentiation among the states in the
determination of which . . . theories,
practices, and approaches will be
utilized’’’) (citation omitted).
In sum, Congress directed that BART
determinations are to be made by the
states, allowing the states to make their
own BART choices based on local
conditions and other considerations.
Because EPA may not exercise authority
‘‘in a manner that is inconsistent with
the administrative structure that
Congress enacted into law,’’ ETSI
Pipeline Project v. Missouri, 484 U.S.
495, 517 (1998), EPA may not
disapprove a state BART determination
that complies with the CAA, whether or
not EPA agrees with the state’s decision.
Here, EPA has not demonstrated that
Wyoming’s BART determination
violates the CAA, and for that reason
EPA must approve the BART
determination in the SIP even if it
‘‘disagrees’’ with it. Instead, just as in its
rulemaking at issue in Texas, EPA’s
Proposed Rule ‘‘transgresses the CAA’s
delineated boundaries of [the]
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5061
cooperative relationship’’ between EPA
and the states. 690 F.3d at 686.
Response: EPA disagrees with this
comment. First, the legislative history of
the 1977 Amendments cited by the
commenter is incomplete. The complete
legislative history, when fairly read,
contradicts the commenter and confirms
EPA’s supervisory role in reviewing
state regional haze SIP submittals,
including the state’s initial BART
determinations.
The 1977 Amendments resulted from
a conference agreement that reconciled
the House bill, H.R. 6161, and the
Senate bill, S. 252. The conference
committee agreed to adopt the visibility
protection provisions of section 116 of
the House bill, with certain
modifications. With respect to the BART
provision in what is now section
169A(b)(2)(A) of the Act, the conference
agreement inserted the phrase ‘‘as
determined by the State (or the
Administrator in the case of a plan
promulgated under [section 110(c) of
the Act])’’ in the two places it now
appears in that section.31 The
conference agreement inserted similar
language into the definition of BART in
section 169A(g)(2). The 1977
Amendments also added section
110(a)(2)(J) to the Act, which makes
(among other things) a regional haze SIP
that meets the requirements of part C
relating to visibility protection a
required part of a state’s SIP.
Thus, H.R. 6161 required states to
submit regional haze SIPs containing
BART determinations, but did not
explicitly specify that the BART
determinations should, in the first
instance, be made by the state. The
conference agreement language clarified
that states should make BART
determinations as part of their SIP
submittals, as explained in the
conference report:
The agreement clarifies that the State,
rather than the Administrator, identifies the
source that impairs visibility in the Federal
class I areas identified and thereby fall
within the requirements of this section. . . .
In establishing emission limitations for any
source which impairs visibility, the State
shall determine what constitutes ‘‘best
available retrofit technology’’ (as defined in
this section) in establishing emission
limitations on a source-by-source basis to be
included in the State implementation plan so
as to carry out the requirements of this
section.
31 The conference agreement also revised the
language ‘‘except as otherwise provided pursuant to
subsection (c), a requirement that each major
stationary source (as defined in section 302(o))
which is in existence on the date of enactment of
this section, but which has not been in operation
for more than 15 years as of such date’’ in H.R. 6161
to its present form. This revision does not affect any
issue raised by the commenter.
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H.R. Conf. Rep. 95–564, at 155 (1977)
(emphasis added). In other words,
BART determinations are a required
element (‘‘the State shall determine’’) of
a state’s regional haze SIP submittal (‘‘to
be included in the State implementation
plan’’). However, the conference report
does not say that the state’s
determination is final. For example, it
does not say: ‘‘The State shall
determine, and EPA shall abide by . . .’’
Thus, all the conference report says is
that states must provide BART
determinations as part of the state’s
required regional haze submittal. As the
Tenth Circuit Court of Appeals stated,
‘‘All the conference agreement
referenced by the D.C. Circuit did was
shift the initial responsibility for making
BART determinations from the EPA to
the state. But that does not differ from
other parts of the CAA—states have the
ability to create SIPs, but they are
subject to EPA review.’’ Oklahoma v.
EPA, 723 F.3d 1201, 1209 (10th Cir.
2013).
Another portion of the legislative
history, only partially quoted by the
commenter, confirms EPA’s supervisory
role. Congressman Rogers inserted into
the Congressional Record a Clean Air
Conference Report (1977): Statement of
Intent; Clarification of Select Principles.
123 Cong. Rec. 27070 (daily ed. Aug. 4,
1977) (statement of Cong. Rogers). The
Statement of Intent clarified ‘‘some
important points on the intention and
effect of the conferees action [that] may
have been overlooked or may be unclear
in the text of the conference bill or the
accompanying statement of managers.’’
Id. Under section ‘‘D. Visibility
protection,’’ the first full paragraph
states:
The conferees essentially agreed to the
House provision for visibility protection. The
provision was modified to give States a
greater role in identifying sources which are
contributing (or may in the future contribute)
to visibility problems and in establishing
control requirements for those sources.
However, the conferees rejected a motion to
delete the national goal. The conferees also
rejected a motion to delete EPA’s supervisory
role under section 110 to assure that the
required progress toward that goal will be
achieved by the revised State plan. If a State
visibility protection plan is not adequate to
assure such progress, then the Administrator
must disapprove that portion of the SIP and
promulgate a visibility protection plan under
section 110(c). Thus, visibility protection in
most mandatory federal Class I areas remains
a national commitment, which is nationally
enforceable.
Id. (emphasis added). Thus, the
Statement of Intent, instead of
supporting the commenter’s arguments,
confirms EPA’s supervisory role over
states’ regional haze SIPs, as the
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conferees deliberately rejected a
proposal to remove that supervisory
role.32 The Statement of Intent also only
describes states as having a ‘‘greater
role’’ in determining BART; it does not
describe that role as exclusive.
With respect to Senator Muskie’s
statements, the comment omits a
portion of the legislative history
regarding application of the BART
Guidelines. Oklahoma v. EPA, 723 F.3d
1201, 1209–10 (10th Cir. 2013). The
Tenth Circuit considered those
statements in context and confirmed
EPA’s authority to ensure that state
BART determinations for fossil-fuel
fired power plants having a total
generating capacity greater than 750
MW complied with the BART
Guidelines. Id. With respect to the
separate views of several
Representatives regarding visibility
protection as unrelated to public health,
those views are of a small minority that
opposed any provisions for visibility
protection whatsoever. H.R. Rep. 95–
294, at 530 (1977). Their views did not
carry the day and, in any case, are
irrelevant to the question of EPA’s
supervisory role.
With respect to the remainder of the
comment regarding various court
opinions, we have responded to similar
comments elsewhere. EPA’s action here
violates neither the holdings in
American Corn Growers and UARG
regarding the RHR, nor the generic
remarks regarding cooperative
federalism in the other cited cases.
Comment: Although EPA cites
‘‘errors’’ made by Wyoming in its BART
determination for Laramie River Station,
EPA has not—and cannot—demonstrate
that any of these alleged ‘‘errors’’
represents a violation of the CAA. These
are technical disagreements over
judgments committed by Congress to the
states—not grounds for EPA to step in
and dictate a technology choice. Section
169A does not confer any authority
upon EPA to make a BART
determination when the state has made
one. Once the state makes a BART
determination, EPA’s authority to
review it in the SIP review process is
very limited. Section 110 mandates that
‘‘[EPA] shall approve such [SIP]
submittal as a whole if it meets all of the
applicable requirements of this
chapter.’’ 42 U.S.C. 7410(k)(3). See also
32 In context, the statement regarding ‘‘required
progress’’ must be understood to include BART.
First, the preceding portion of the statement
discusses States’ roles in determining controls
generally under 169A(b)(2), ‘‘including’’ the BART
requirements in 169A(b)(2)(A). The portion about
EPA’s supervisory role in assuring ‘‘required
progress’’ should be understood to apply to all of
169A(b)(2), including subsection 169A(b)(2)(A).
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Forest Guardians v. Babbitt, 174 F.3d
1178, 1187 (10th Cir. 1999) (‘‘The
Supreme Court and this circuit have
made clear that when a statute uses the
word ‘shall,’ Congress has imposed a
mandatory duty upon the subject of the
command.’’).
As the Fifth Circuit recently
expressed, ‘‘the Act confines the EPA to
the ministerial function of reviewing
SIPs for consistency with the Act’s
requirements,’’ and ‘‘[t]h[e] statutory
imperative [of section 110(k)(3)] leaves
the agency no discretion to do anything
other than ensure that a state’s
submission meets the CAA’s
requirements and, if it does, approve it.’’
Luminant, 675 F.3d at 921, 926. See also
id. at 932 (‘‘If [the State’s] regulations
satisfy th[e] basic requirements [of the
CAA], the EPA must approve them, as
section 7410(k)(3) requires. That is the
full extent of the EPA’s authority in the
SIP-approval process because that is all
the authority that the CAA confers.’’)
Texas, 690 F.3d at 676 (‘‘[I]f a SIP or a
revised SIP meets the statutory criteria
of the CAA, then the EPA must approve
it.’’); Bethlehem Steel Corp. v. Gorsuch,
742 F.2d 1028, 1036 (7th Cir. 1984)
(EPA’s SIP disapproval power is
‘‘constrained by the substantive criteria
in 42 U.S.C. 7410(a)(2)(A)–(K)’’); Fla.
Power & Light Co. v. Costle,650 F.2d
579, 581 (5th Cir. 1981) (‘‘If a SIP or a
revised SIP meets the statutory criteria.
. . the EPA must approve it.’’)
(citations omitted).
Since Wyoming’s BART decision for
Laramie River Station, along with its
associated SIP revision, meets the
requirements set forth in the CAA, EPA
has no discretion and must approve it
in its entirety. As the Supreme Court
explained in the NAAQS context: The
Act gives the Agency no authority to
question the wisdom of a state’s choices
of emission limitations if they are part
of a plan which satisfies the standards
of section 110(a)(2), and the Agency
may devise and promulgate a specific
plan of its own only if a state fails to
submit an implementation plan which
satisfies those standards. Section 110(c).
Thus, so long as the ultimate effect of a
state’s choice of emission limitations is
compliance with the national standards
for ambient air, the state is at liberty to
adopt whatever mix of emission
limitations it deems best suited to its
particular situation. Train, 421 U.S. at
79; see also Virginia, 108 F.3d at 1408–
10 (confirming that the 1977
Amendments to section 110 did not
alter the division of responsibilities
recognized in Train). Accord Union
Elec. Co. v. EPA, 427 U.S. 246, 267
(1976) (‘‘[T]he State has virtually
absolute power in allocating emission
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limitations so long as national standards
are met.’’).
The fact that states must propose SIP
revisions ‘‘as may be necessary’’ to
achieve reasonable progress does not
mean that EPA has authority to
countermand the textual commitment to
leave BART decisions to the states. The
D.C. Circuit interpreted similar language
in Section 110(k)(5) to constrain EPA’s
authority over SIP approval and
disapproval. See Virginia, 108 F.3d at
1409. The SIP call provisions of Section
110(k)(5) similarly state that when a SIP
is inadequate ‘‘[EPA] shall require the
State to revise the plan as necessary to
correct such inadequacies.’’ But the
Virginia court rejected the agency’s
expansive view of this phrase as
authority to impose specific control
measures for specific emission sources:
EPA apparently thinks the ‘‘as
necessary’’ language in section 110(k)(5)
altered the division of responsibilities
between the states and the agency. We
suppose the idea is that because section
110(k)(5) empowers EPA to ‘‘require the
State to revise the plan as necessary to
correct’’ inadequacies, it empowers EPA
to require the state to include particular
control measures in the revised plan.
There is nothing to this. Id. at 1409.
Instead, the court concluded that this
phrase ‘‘keep[s] EPA within bounds.’’
Id. at 1410. Imposition of a FIP is
intended to be a drastic penalty,
imposed only where a state fails to
provide the air pollution reductions
required by the CAA, as ‘‘it rescinds
state authority to make the many
sensitive and policy choices that a
pollution control regime demands.’’’ Id.
at 1406–07 (citation omitted). The court
also expressed, in rejecting EPA’s
interpretation of Section 110(k)(5), that
‘‘[w]e would have to see much clearer
language to believe a statute allowed a
federal agency to intrude so deeply into
state political processes.’’ Id. at 1410.
EPA must therefore approve the
Wyoming SIP as it relates to BART at
Laramie River Station, as compliance
with the law is all that is required. See
Luminant, 675 F.3d at 926 (EPA’s
reliance on factors other than
compliance with the CAA in
disapproving a SIP violated the
Administrative Procedures Act (APA),
as it was ‘‘in excess of statutory
authority,’’ and was arbitrary and
capricious, as it considered ‘‘a ‘factor[ ]
which Congress has not intended [the
EPA] to consider’ ’’) (quoting 5 U.S.C.
706(2)(C) and State Farm, 463 U.S. at
43) (alteration in original).
Response: EPA is not substituting its
judgment on required technology for the
State’s in this decision. Rather, we have
determined that Wyoming’s analysis
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and determinations were not performed
consistent with the CAA and
implementing regulations. EPA
considered the State’s SIP as well as the
most recent information submitted by
Basin Electric and others for the
Laramie River BART units. As
explained in detail in our response to
similar comments in the BART section
of this document, we found Basin
Electric’s estimates of SCR capital cost
deficient in a number of respects,
specifically: (1) Inadequate explanation
for the high labor rates that were
assumed when compared to published
labor rates; (2) High overtime and per
diem costs without sufficient
explanation; (3) Apparent duplication of
costs associated with General Facilities;
(4) Inclusion of AFUDC; (5) Apparent
duplication of contingencies and other
cost adders; and (6) Addition of
unnecessary SO3 mitigation system. All
of these contributed to excessively high
capital cost. Sargent & Lundy also
assumed excessively high cost for
replacement catalyst, which contributes
to high operating cost. As we explain
elsewhere, these deficiencies are
inconsistent with the CAA and RHR.
We responded to similar comments
regarding the remaining comments
above and elsewhere in this document.
Comment: To the extent that the
Supreme Court in ADEC suggested it
was adopting a ‘‘reasonableness’’
standard, and did not expressly state
that what it was doing was adopting an
‘‘arbitrary and capricious’’ standard, the
Supreme Court and other federal courts
have confirmed that these two standards
are nearly interchangeable. Moreover, to
the extent that there is any perceivable
difference between the two standards,
these cases confirm that ‘‘reasonable’’
means something more like ‘‘not
arbitrary and capricious’’ than ‘‘not
what EPA would prefer.’’ See, e.g.,
Marsh v. Ore. Nat. Res. Council, 490
U.S. 360, 377 n.23 (1989) (‘‘as some of
the[ ] courts have recognized, the
difference between the ‘arbitrary and
capricious’ and ‘reasonableness’
standards is not of great pragmatic
consequence’’) (citing cases); Ridenour
v. Kaiser-Hill Co., 397 F.3d 925, 939
(10th Cir. 2005) (‘‘When a party
challenges agency action as arbitrary
and capricious the reasonableness of the
agency’s action is judged in accordance
with its stated reasons.’’) (citation
omitted); Amisub (PSL), Inc. v. Colo.
Dep’t of Social Servs., 879 F.2d 789, 800
(10th Cir. 1989) (the court’s role in
applying the arbitrary and capricious
review standard is ‘‘to determine if there
was a reasonable factual basis to
support’’ the agency’s findings); United
States v. Minnkota Power Co-Op Inc.,
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831 F. Supp.2d 1109, 1119 (D.N.D.
2001) (expressing that the
‘‘reasonableness’’ standard employed by
the ADEC Court is the same as the
‘‘arbitrary and capricious’’ standard).
Under the APA’s arbitrary and
capricious review standard,
administrative action is presumed valid,
and review of that action is ‘‘ ‘narrow in
scope.’ ’’ Copar Pumice Co. v. Tidwell,
603 F.3d 780, 793 (10th Cir. 2010)
(citation omitted). ‘‘Agency action is
arbitrary and capricious only if the
agency ‘has relied on factors which
Congress has not intended it to
consider, entirely failed to consider an
important aspect of the problem, offered
an explanation for its decision that runs
counter to the evidence before the
agency,’ or if the agency action ‘is so
implausible that it could not be ascribed
to a difference in view or the product of
agency expertise.’ ’’ Id. (quoting State
Farm, 463 U.S. at 43). A court will not
‘‘substitute [its] judgment for that of the
agency,’’ but will only consider whether
the agency provided a ‘‘reasoned basis’’
for its action. Id. at 793–94 (quoting
State Farm, 463 U.S. at 43). The courts
also have developed a series of related
standards designed to ensure that courts
afford appropriate deference to an
agency’s technical and policy choices,
and refrain from substituting the courts’
judgment for that of the agency. For the
same reasons that arbitrary and
capricious review should apply to EPA’s
review of a state BART determination,
these related standards also should
apply: (1) The State’s BART decision is
presumed valid, and EPA bears the
burden of proving otherwise, see
Hillsdale Envt’l Loss Prevention, Inc. v.
U.S. Army Corps of Eng’rs, 702 F.3d
1156, 1165 (10th Cir. 2012); (2) the
State’s decision may be set aside ‘‘ ‘only
for substantial procedural or substantive
reasons,’ ’’ id. (citation omitted); and (3)
where experts might disagree about a
technical issue, EPA must defer to the
‘‘reasonable opinions’’ of the States’
experts, see Colo. Wild v. U.S. Forest
Serv., 435 F.3d 1204, 1214 (10th Cir.
2011). See also Minnkota Power, 831 F.
Supp.2d at 1119–20 (the same
principles that apply to court review of
agency action under the APA apply to
EPA challenges to state BACT
determinations).
EPA’s proposal does not formulate or
apply these standards, and thus does
not establish grounds to overrule the
State’s BART determination for Basin
Electric’s Laramie River Station. EPA
has not found that Wyoming ‘‘entirely
failed to consider an important aspect of
the problem,’’ considered factors
Congress did not intend it to consider,
or reached a decision ‘‘so implausible’’
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as to be arbitrary. Nor has EPA found
that Wyoming’s explanation for its
decision runs counter to the evidence
that was before it. Instead, EPA
complains of minor alleged deviations
from broadly worded and highly flexible
guidelines deliberately designed to be
consulted but not rigidly adhered to in
any event. EPA therefore must approve
the State’s BART decision for Laramie
River, as any other result represents
EPA’s substitution of its judgment over
Wyoming’s, which EPA has no statutory
authority to do.
Response: EPA disagrees with this
comment, which is based on a
fundamental misunderstanding of EPA’s
role. In acting on a state’s SIP submittal,
EPA does not sit in the position of a
reviewing federal court. Instead, EPA is
the agency entrusted by Congress with
administering the CAA. Thus Congress
has ‘‘vested EPA with explicit and
sweeping authority to enforce CAA
requirements’’ and requires that ‘‘EPA
step in to ensure that the statutory
requirements are honored.’’ Alaska
Dep’t of Envtl. Conservation v. EPA, 540
U.S. 461, 490 (2004). Reviewing courts,
on the other hand, ‘‘are not experts in
the field’’ and thus defer to decisions by
‘‘the agency charged with the
administration of the statute.’’ Chevron,
Inc. v. Natural Res. Def. Council, 467
U.S. 837, 866 (1984).
In the context of acting on a regional
haze SIP, EPA must assure that it meets
the requirements of the Act and the
RHR, including requirements regarding
BART. EPA—unlike a reviewing court—
is not required to defer to the state’s
technical judgments. Instead, EPA is not
only authorized, but required to exercise
independent technical judgment in
evaluating the adequacy of a state’s
regional haze SIP, including its BART
determinations, just as EPA must
exercise such judgment in evaluating
other SIPs. In evaluating other SIPs,
EPA’s role is always to make a judgment
about SIP adequacy, not just to meet and
maintain the NAAQS, but also to meet
other requirements that do not have a
numeric value. In this case, Congress
did not establish NAAQS by which to
measure visibility improvement;
instead, it established a reasonable
progress standard and required that EPA
assure that such progress be achieved.
Here, contrary to the commenter’s
assertion, we are exercising judgment
within the parameters laid out in the
CAA and our regulations. Our
interpretation of our regulations and of
the CAA, and our technical judgments,
are entitled to deference. See, e.g.,
Michigan Dep’t. of Envtl. Quality v.
Browner, 230 F.3d 181 (6th Cir. 2000);
Connecticut Fund for the Env’t., Inc. v.
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EPA, 696 F.2d 169 (2nd Cir. 1982);
Voyageurs Nat’l Park Ass’n v. Norton,
381 F.3d 759 (8th Cir. 2004); Mont.
Sulphur & Chem. Co. v. EPA, 666 F.3d
1174 (9th Cir. 2012).
The comment does not cite to
anything in the ADEC opinion (or, for
that matter, in the CAA itself) that
suggests EPA must, in reviewing a SIP
submittal, adopt the APA standards of
review. Instead, in ADEC the Supreme
Court upheld EPA’s position that the
State permitting agency’s BACT
determination ‘‘did not qualify as
reasonable in light of the statutory
guides.’’ Alaska Dep’t of Envtl.
Conservation v. EPA, 540 U.S. 461, 484
(2004). The mere coincidence that some
courts have described the APA
standards of review as essentially a
‘‘reasonableness’’ standard does not
compel EPA to adopt the APA standards
of review; nor did the ADEC opinion
suggest EPA must do so. As explained
above, a fundamental difference
between EPA and a reviewing court is
that courts lack technical expertise and
so generally defer to agency technical
judgments; on the other hand, EPA is
the expert agency entrusted by Congress
with administering the CAA and
exercising its best technical judgment in
doing so. Another fundamental
difference is that a reviewing court is
limited to the record compiled by the
administrative agency, but EPA in its
review of a SIP submittal is not limited
just to the record compiled by the state
agency, and may supplement the record
with (among other things) EPA’s own
expert reports and analyses. In fact, if
the cases cited by the commenter
discussing the APA standard of review
stand for anything, it is the proposition
that if and when EPA’s action on this
SIP submittal is subject to judicial
review, the court will base its decision
on the record compiled by EPA and give
appropriate deference to EPA’s
technical judgments and interpretations
of the Act and the RHR. Accordingly,
the Eighth and Tenth Circuit Court of
Appeals have applied the APA standard
of review to EPA’s actions on other
regional haze SIP submittals. See
Oklahoma v. EPA, 723 F.3d 1201 (10th
Cir. 2013), North Dakota v. EPA, 730
F.3d 750 (8th Cir. 2013).
The discussion of the standard of
review in the district court’s order and
opinion in United States v. Minnkota
Power Co-op., Inc., 831 F. Supp. 2d
1109 (D.N.D. 2011), cited by commenter,
is not to the contrary. The district
court’s opinion first quotes the ADEC
opinion for the proposition that the
question presented is whether ‘‘the state
agency’s BACT determination was
reasonable, in light of the statutory
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guides and the state administrative
record.’’ Id. at 1119 (emphasis added).
The district court’s opinion then again
quotes the ADEC opinion: ‘‘We apply
the familiar default standard of the
Administrative Procedure Act . . . and
ask whether the Agency’s action was
‘arbitrary, capricious, an abuse of
discretion, or otherwise not in
accordance with law.’ ’’ Id. (emphasis
added). In the context of the ADEC
opinion, the Agency referred to by the
Supreme Court in the second quote is
EPA, not the State agency. The district
court’s opinion then continues by
quoting a separate Supreme Court
opinion discussing the similarities of
the arbitrary and capricious standard
and the reasonableness standard. This
fails to establish any sort of connection
between the APA standard and EPA’s
review of a state determination. In
addition, Minnkota Power took place in
the context of an enforcement action,
not action on a SIP submittal. The EPA
had entered into a consent decree that
(among other things) ‘‘establishe[d] the
standard of review governing the EPA’s
challenge to the North Dakota NOX
BACT Determination.’’ Id. at 1112. The
consent decree provided that ‘‘[t]he
disputing Party shall bear the burden of
proof throughout the dispute resolution
process.’’ Thus, Minnkota Power has
nothing to say about use of the APA
standard in EPA’s review of a state’s
BART determination.
Comment: In applying the arbitrary
and capricious standard, EPA should
accord the same deference to a state’s
BART determination that courts accord
to an agency decision under the
National Environmental Policy Act
(NEPA), which, like section 169A, ‘‘does
not mandate particular results, but
simply prescribes the necessary
process.’’ Robertson v. Methow Valley
Citizens Council, 490 U.S. 332, 350
(1989). See also 42 U.S.C. 4332(2)(C)
(any agency contemplating a ‘‘major
Federal action [that] significantly
affect[s] the quality of the human
environment’’ must prepare an
environmental impact statement [EIS]
analyzing the action’s environmental
effects). Under NEPA, ‘‘[t]he role of the
courts is simply to ensure that the
agency has adequately considered and
disclosed the environmental impact of
its actions and that its decision is not
arbitrary or capricious.’’ Baltimore Gas
& Elec. Co. v. NRDC, 462 U.S. 87, 97–
98 (1983).
The purpose of this deferential review
standard under NEPA is to prevent a
court from ‘‘substitut[ing] its judgment
for that of the agency.’’ Kleppe v. Sierra
Club, 427 U.S. 390, 410 n.21 (1976). As
the Supreme Court explained in Kleppe,
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‘‘[t]he only role for a court is to insure
that the agency has taken a ‘hard look’
at environmental consequences; it
cannot ‘interject itself within the area of
discretion of the executive as to the
choice of the action to be taken.’’’ Id.
(citing NRDC v. Morton, 458 F.2d 827,
838 (D.C. Cir. 1972)).
Under this review standard, ‘‘even if
[the reviewing court] would have made
a different choice had the matter been
before [the court] de novo,’’ the court
‘‘cannot displace the agencies’ choice’’
between conflicting views, evidence,
data, and scientific opinions. Custer
Cnty. Action Ass’n v. Garvey, 256 F.3d
1024, 1036 (10th Cir. 2001). Thus, even
in the face of technical objections, a
court will uphold the agency’s action so
long as it is supported by substantial
evidence in the administrative record, is
adequate to foster informed public
participation and decision making, and
is not otherwise arbitrary or capricious.
Id.
Moreover, as the courts have
repeatedly recognized, ‘‘[d]eficiencies in
an EIS that are mere ‘flyspecks’ and do
not defeat NEPA’s goals of informed
decision making and informed public
comment will not lead to reversal.’’’
WildEarth Guardians v. NPS, 703 F.3d
1178, 1183 (10th Cir. 2013) (quoting
New Mexico v. BLM, 565 F.3d 683, 704
(10th Cir. 2009)). See also Custer Cnty,
256 F.3d at 1035 (‘‘Our objective is not
to ‘fly speck’ the [EIS], but rather, to
make a ‘pragmatic judgment whether
the [EIS]’s form, content and
preparation foster both informed
decision-making and informed public
participation.’’’) (citation omitted).
The same principles apply here,
where Congress has expressly delegated
the BART decision to the states, did not
mandate the states to reach a specific
outcome, and established only a
decision making process for the states to
follow—not a required outcome. If the
state considered all five statutory factors
to arrive at a result that improves
visibility, and its decision is not
arbitrary, capricious, an abuse of
discretion, or otherwise not in
accordance with law, EPA must affirm
the BART selection—even if EPA would
or could have made a different
selection.
Response: EPA disagrees with this
comment. The comment does not
identify anything in the NEPA court
decisions that demonstrates that those
decisions are applicable to EPA’s review
of a SIP submittal. In fact, Section 7(c)
of the Energy Supply and
Environmental Coordination Act of
1974 (15 U.S.C. 793(c)(1)) exempts
actions under the CAA from the
requirements of NEPA. Specifically, this
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section states that ‘‘[n]o action taken
under the CAA [42 U.S.C. 7401 et seq.]
shall be deemed a major Federal action
significantly affecting the quality of the
human environment within the meaning
of the National Environmental Policy
Act of 1969 [42 U.S.C. 4321 et seq.].’’
While the standard of review for EPA’s
SIP and FIP decisions may be similar to
that under NEPA,33 the NEPA decisions
simply are not applicable in the CAA
context.
Furthermore, NEPA relies solely on
‘‘procedural mechanisms—as opposed
to substantive, result-based standards.’’
Robertson v. Methow Valley Citizens
Council, 490 U.S. 332, 353 (1989).
Unlike NEPA, the CAA’s regional haze
program has specific substantive
requirements, and EPA must ensure that
SIP submittals meet the requirements of
the Act, including the substantive
provisions of the regional haze program.
See CAA Section 110(a)(2)(J) (SIP
submittals must meet applicable
requirements of Part C of title I,
including visibility protection). As the
Eighth Circuit Court of Appeals stated:
‘‘EPA is left with more than the
ministerial task of routinely approving
SIP submissions.’’ North Dakota v. EPA,
730 F.3d 750 (8th Cir. 2013) (emphasis
added).
Comment: One commenter asserted
that the U.S. Supreme Court and the
lower federal courts have long
recognized and applied the principle of
‘‘harmless error’’ where an agency may
have committed an error, but that error
did not affect the outcome of its
decision. See, e.g., Nat’l Ass’n of Home
Builders v. Defenders of Wildlife, 551
U.S. 644, 659 (2007); Hillsdale, 702 F.3d
at 1165. See generally 5 U.S.C. 706
(‘‘[D]ue account shall be taken of the
rule of prejudicial error.’’).
The commenter argued that the courts
also have long recognized the related
principle that agencies may ‘‘overlook
circumstances that in context may fairly
be considered de minimis,’’ as part of
the broad notion that ‘‘the law does not
concern itself with trifling matters.’’
Alabama Power Co. v. Costle, 636 F.2d
323, 360 (D.C. Cir. 1979). Thus, for
instance, the D.C. Circuit rejected a
33 By statute, EPA’s promulgation of a FIP must
be upheld unless the court determines EPA’s action
was ‘‘arbitrary, capricious, an abuse of discretion,
or otherwise not in accordance with the law.’’ CAA
Section 307(d)(1)(B), (9)(A). There is no statutory
standard of review governing EPA’s disapproval of
a SIP, however, the Supreme Court has held that
where the Clean Air Act does not specific a
standard for judicial review, ‘‘we apply the familiar
default standard of the Administrative Procedure
Act . . . and ask whether the agency’s action was
arbitrary, capricious, an abuse of discretion, or
otherwise not in accordance with law.’’ ADEC at
496–97.
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challenge to a Federal Aviation
Administration rule where the agency
had used ‘‘inappropriate guidelines for
measuring the effects of noise’’ in its
determination that a proposed airport
site would not result in any ‘‘use’’ of a
nearby wildlife refuge. Allison v. Dep’t
of Transp., 908 F.2d 1024, 1026 (D.C.
Cir. 1990). The court cited the APA
provision requiring consideration of
‘‘prejudicial error,’’ and expressed that
‘‘[a] court should not upset a decision
because of errors that are not material.’’
Id. at 1029 (citations omitted). See also
Grunman Data Sys. Corp. v. Widnall, 15
F.3d 1044, 1048 (Fed. Cir. 1994)
(rejecting bid protest although agency
may have violated accounting principles
in its analysis of the best value bid, as
any accounting errors were ‘‘de
minimis,’’ and stating that ‘‘overturning
awards on de minimis errors wastes
resources and time, and is needlessly
disruptive of procurement activities and
governmental programs and
operations’’) (citation omitted).
Finally, the commenter argued, the
courts have repeatedly held that agency
action should not be reversed due to
mere calculation errors that do not
render a rule arbitrary and capricious.
See, e.g., Michigan v. EPA, 213 F.3d
663, 691 (D.C. Cir. 2000) (rejecting
challenge to EPA decision despite error
in calculation); Chem. Mfrs. Ass’n v.
EPA, 870 F.2d 177, 241, clarified on
reh’g, 885 F.2d 253 (5th Cir. 1989)
(same); CPC Int’l, Inc. v. Train, 540 F.2d
1329, 1343–44 (8th Cir. 1976) (same).
The commenter stated that these same
principles should apply to EPA’s review
of the State’s BART determinations,
such that EPA has no authority to
disapprove the State’s decisions if a
deviation from the BART Guidelines
and CCM was merely de minimis and at
most harmless error that did not affect
the State’s selection of BART. Indeed,
EPA’s approach itself suggests that the
BART Guidelines and CCM were
intended to be flexible, and that EPA’s
review of compliance with their
provisions is subject to a materiality
standard. For instance, in the Proposed
Rule, EPA proposes to disapprove
certain BART determinations based on
purported deviations from the BART
Guidelines and CCM in assessing cost
and visibility, yet it also proposes to
approve other BART determinations
‘‘because [it has] determined that the
State’s conclusions were reasonable
despite the cost and visibility errors’’
identified by EPA. 78 FR 34750. And,
while the Tenth Circuit’s decision in
Oklahoma v. EPA is not yet final, as
petitions for rehearing may yet be filed,
that court similarly suggested that there
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was a materiality element to a state’s
compliance with the BART Guidelines,
noting, in particular, that the State’s cost
estimates were ‘‘more than ten times
EPA’s stated average costs per ton for
th[e] technology, and nearly five times
as much as the upper limit of EPA’s
expected cost range.’’ —F.3d—, 2013
U.S. App. LEXIS 14634, at *25 (10th Cir.
July 19, 2013). Notably, that case did not
involve SCR technology, which the
CCM affords a greater amount of
flexibility in assessing, and the State
had failed to note and explain its
deviations from the CCM.
By applying these principles here, the
commenter asserted, any deviation from
the BART Guidelines and CCM was de
minimis, and mere harmless error.
Certainly, EPA has not shown that the
State would have made a different
BART selection had it assessed the cost
and visibility factors in the manner EPA
suggests—particularly as the selection of
BART must be made by weighing all
five factors, and as the differences
between the State’s and EPA’s
assessments of cost and visibility are not
so substantial as to necessitate a
different result. In other states, EPA has
acknowledged that a state’s BART
determination may be disapproved on
account of a claimed error only if the
error would have changed the BART
determination. In approving Colorado’s
regional haze SIP, EPA did not
disapprove the BART determination for
the Martin Drake power plant, despite
EPA’s disagreement regarding the
control efficiency of SCR because the
discrepancy would not have changed
the outcome. 77 FR 76871, 76875–76
(Dec. 31, 2012) (‘‘[We] find that it was
not unreasonable for Colorado to use
0.07 lb/MMBtu to model the predicted
visibility improvement from SCR.
Moreover, while we do agree that
assuming a control efficiency of 0.05 lb/
MMBtu would have resulted in greater
modeled visibility benefits, we do not
agree that the difference in visibility
benefits would have led Colorado to a
different conclusion given the
magnitude of the benefits associated
with SCR.’’). The commenter advocated
that EPA should take a similar approach
in Wyoming.
The commenter finished by stating
that if there is a question as to whether
the State might have made a different
BART selection had it assessed cost and
visibility in the manner suggested by
EPA, EPA should return the issue to the
State to reweigh the BART factors with
that information. See SKF USA Inc. v.
United States, 254 F.3d 1022, 1029 (Fed.
Cir. 2001) (courts may remand matters
to the agency upon request to correct
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‘‘clerical errors, transcription errors, or
erroneous calculations’’).
Response: The cases cited to by the
commenter all concern standards by
which courts evaluate agency action,
not standards by which EPA, an
administrative agency, evaluates SIP
submissions for compliance with the
requirements of the CAA. The cases are
therefore inapposite. Nevertheless, in
situations where a state’s SIP reaches a
reasonable result overall despite
violations of certain statutory or
regulatory requirements, EPA believes
that approving the SIP is sometimes a
better use of scarce administrative
resources and more in line with
principles of cooperative federalism
than promulgating a FIP. This approach
is arguably similar to the principle of
‘‘harmless error’’ that courts adhere to in
the context of judicial review.
In this situation, however, the errors
committed by Wyoming in its regional
haze SIP were neither harmless nor de
minimis. As we have explained
previously, because Wyoming did not
properly calculate the costs of the
various control options or accurately
estimate the visibility improvement
associated with these controls, the
State’s ultimate selection of BART for
several EGUs did not represent the best
system of continuous emission
reduction. As the Eighth and Tenth
Circuits have recently held, EPA acts
within its power under section 169A of
the CAA when it rejects a BART
determination on the basis that a state
did not properly take into consideration
the costs of compliance as a result of
methodological or data flaws. See
Oklahoma v. EPA, 723 F.3d 1201, 1212
(10th Cir. 2013); North Dakota v. EPA,
730 F.3d 750 (8th Cir. 2013). This same
reasoning applies equally to the other
statutory BART factors, such as
visibility improvement.
We also disagree with the commenter
that our action on the Colorado regional
haze SIP implies that a similar outcome
is warranted here. In that action, we
stated that ‘‘it was not unreasonable for
Colorado to use 0.07 lb/MMBtu to
model the predicted visibility
improvement from SCR.’’ 77 FR 76871,
76875 (Dec. 31, 2012). Thus, we did not
disagree with Colorado’s choice of
control efficiency, as the commenter
claims, and the situation bears no
relationship to this one, where we have
carefully explained our disagreement
with multiple aspects of Wyoming’s
NOX BART determinations.
Finally, we decline to ‘‘return the
issue to the State,’’ as the commenter
proposes. At this time, the Wyoming
regional haze SIP is many years
overdue, and the deadline for EPA to
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issue a FIP has long since passed. We
note, however, that Wyoming is free to
submit a SIP revision at any time that,
if approved, could replace all or a
portion of EPA’s FIP.
Comment: EPA’s proposal to
disapprove Wyoming’s BART
determination for Laramie River not
only overrides the State’s technical
judgment but also renders moot with a
stroke of a pen the extensive judicial,
administrative, and political processes
developed by the State to implement its
obligations under the CAA as a separate
sovereign. Wyoming has enacted a
robust and independent set of
administrative and judicial procedures
to review and potentially overturn
BART decisions made by the State.
These procedures are part of the State’s
SIP expressly approved by EPA, 40 CFR
52.2620, making them federally
enforceable.
Wyoming’s air quality regulations
require a source subject to BART to
apply for and obtain a BART permit. In
this case, Laramie River Station’s BART
permit was issued pursuant to Wyoming
Air Quality Standards and Regulations
(WAQSR) Chapter 6, Sections 2 and 9.
The rules requiring BART permits in
Wyoming were adopted on October 9,
2006 as a new section to meet the
requirements of EPA’s RHR. Chapter 6
requires facilities seeking permits to
comply with all the rules and
regulations of Wyoming. Chapter 6,
Section 9 of the Air Quality Division’s
rules and regulations govern BART
permits. Section 9(e)(iv) requires that
the opportunity for public comment on
BART permits follow the procedures
specified in Chapter 6, Section 2(m).
That section, in turn, establishes a
notice and comment procedure that
specifically requires a copy of the public
notice to be sent to EPA. Thus, EPA
approved Wyoming’s plan that
specifically contemplates EPA’s
inclusion in State administrative review
proceedings. See 40 CFR 52.2620; see
also US Magnesium, LLC v. EPA, 690
F.3d 1157, 1159 (10th Cir. 2012) (EPA’s
approval of a State’s SIP gave the SIP
the force and effect of federal law).
Here, EPA received the required
notice at every step of the proceedings.
EPA, however, chose to participate to
only a limited extent. After submitting
August 3, 2009 comments to the State’s
BART Application Analysis and
proposed permit and October 26, 2009
comments to Wyoming’s draft regional
haze SIP, EPA excised itself from the
process. Despite its prior comments on
Basin Electric’s BART permit and the
regional haze SIP, EPA did not seek to
intervene in Basin Electric’s
administrative appeal to the
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Environmental Quality Council or
comment on Basin Electric’s settlement
agreement with the Environmental
Quality Council. EPA could have
advised the Environmental Quality
Council that it believed the proposed
settlement violated the CAA or was
otherwise arbitrary and capricious, but
it did not. Instead, illustrating its
disregard for State primacy, EPA now
proposes to disapprove the NOX BART
emissions limits in the settlement
agreement and final SIP, years after the
administrative process concluded.
As the dissenters in ADEC described,
EPA should not be permitted to avoid a
‘‘more painstaking state process by a
mere stroke of the pen under the
agency’s letterhead.’’ 540 U.S. at 509
(Kennedy, J., dissenting) (discussing an
analogous process for BACT
determinations). The CAA’s ‘‘strict’’
division of authority creates a ‘‘statutory
federalism bar [that] prohibits EPA from
using the SIP process to force States to
adopt specific control measures.’’ EME
Homer City Generation, L.P. v. EPA, 696
F.3d 7, 29 (D.C. Cir. 2012) (citing
Virginia, 108 F.3d at 1410). But that is
precisely what EPA seeks to do here.
EPA’s approach both confuses the CAA
‘‘with a general administrative law
statute like the [APA]’’ and upsets ‘‘the
balance between State and Federal
Governments.’’ See ADEC, 540 U.S. at
507–17 (Kennedy, J., dissenting).
Simply put, it is inappropriate for EPA
to dodge the administrative and judicial
review process established in the State
of Wyoming through overturning of
Wyoming’s BART decision by
administrative fiat. See id. at 510
(Kennedy, J., dissenting). It was only
after Wyoming submitted its regional
haze SIP to EPA that EPA announced it
found the settlement ‘‘unreasonable’’
and something with which it
‘‘disagreed.’’ Based upon these
assertions, and without demonstrating
that the BART permit actually violates
the CAA, EPA now proposes to void all
the extensive administrative
proceedings, processes, comment
periods, and permit finality accorded
under State law.
This improperly impinges upon state
authority. Under the regional haze
program, deference to state authority is
far more compelling than issues related
to public health under the BACT
program, and so the Supreme Court’s
holding in ADEC that EPA may not
require ‘‘recourse to state processes’’ is
inapplicable to BART decisions. ADEC,
541 U.S. at 492. EPA should conduct
itself in accordance with the spirit of its
representation to the Supreme Court
that it has never sought to override a
state court judgment, and should not
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seek to override a state BART decision
that has been litigated to administrative
conclusion under state law, particularly
where, as here, EPA never advised the
State adjudicators or the parties to the
State proceedings that it considered the
permit to be invalid under the CAA.
EPA could have participated in the State
administrative appeal proceeding or, at
a minimum, appeared in the proceeding
to register an objection to the settlement
agreement. Having elected not to do so,
EPA should respect the result of the
State’s process. Alternatively, EPA is
precluded from overruling the Laramie
River BART permit decision that
resulted from that process. ADEC, 540
U.S. at 491 n.14. EPA had notice and
ample opportunity to contest the
appropriateness and legality of the
BART permit in Wyoming, but simply
chose not to do so.
EPA is not free to let parties like Basin
Electric spend thousands of dollars and
years of effort resolving the terms of a
BART permit, only to find the process
wasted because EPA disagrees yet chose
to ignore multiple notices of the State
proceedings. Absent application of
claim preclusion under these
circumstances, EPA could effectively
‘‘rescind[ ] state authority to make the
many sensitive and policy choices that
a pollution control regime demands.’’
Virginia, 108 F.3d at 1406–07 (citation
omitted). Here, EPA does not intrude
upon state political processes; it ignores
them, upsetting ‘‘the balance between
State and Federal Governments.’’ See
ADEC, 540 U.S. at 507–17 (Kennedy, J.,
dissenting).
EPA’s interference with State’s
prerogatives also violates the Tenth
Amendment to the United States
Constitution. ‘‘[T]he Tenth Amendment
confirms that the power of the Federal
Government is subject to limits that
may, in a given instance, reserve power
to the States.’’ New York v. United
States, 505 U.S. 144, 157 (1992). See
also U.S. Const. amend. X (‘‘The powers
not delegated to the United States by the
Constitution, nor prohibited by it to the
States, are reserved to the States
respectively, or to the people.’’). Here,
EPA’s rejection of Wyoming’s BART
decision and imposition of its own not
only overrides Congress’ resolution to
leave localized BART analyses in the
hands of the states, but also infringes on
Wyoming’s (and its citizens’) Tenth
Amendment right to have those
decisions made and adjudicated by the
State. See Arlington, 133 S.Ct. at 1874
(although Chevron deference generally
applies to an agency’s interpretation of
the scope of its authority, ‘‘[w]here
Congress has established a clear line,
the agency cannot go beyond it; and
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5067
where Congress has established an
ambiguous line, the agency can go no
further than the ambiguity will fairly
allow’’); Hodel v. Va. Surface Min. &
Reclamation Ass’n, 452 U.S. 264, 289
(1981) (statute survived Tenth
Amendment scrutiny because it
‘‘establishes a program of cooperative
federalism that allows the States, within
limits established by federal minimum
standards, to enact and administer their
own regulatory programs, structured to
meet their own particular needs,’’
instead of ‘‘commandeer[ing] the
legislative processes of the States by
directly compelling them to enact and
enforce a federal regulatory program’’).
Earlier comments provided similar
arguments, by noting that Wyoming
issued its BART Application Analysis
and proposed permit on May 28, 2009,
and accepted public comments on its
analysis and proposed permit for a
period of 60 days, followed by a public
hearing on August 6, 2009. Numerous
comments were received, including
comments from EPA dated August 3,
2009. EPA did not comment that
Wyoming’s proposed BART
determination violated the CAA. Nor
did EPA identify any action taken by
Wyoming in connection with the permit
that was arbitrary or capricious. While
EPA regularly encouraged Wyoming to
consider both SNCR and SCR
technologies, at no point did EPA advise
Wyoming that BART controls of LNBs
and OFA for the Laramie River Station
would violate the CAA or otherwise be
arbitrary and capricious. Basin Electric
appealed its BART permit to the
Environmental Quality Council, arguing
that Wyoming’s imposition of additional
technology requirements in 2018 as part
of its long term goals exceeded its
authority for terms contained in a BART
permit. In its appeal, Basin Electric
accepted LNB and OFA as BART but
objected to the additional permit
condition related to long term strategies.
Basin Electric served its Petition for
Review before the Environmental
Quality Council on EPA, and EPA
received this notice of appeal, as
indicated by its acceptance of the
certified mail forwarding the appeal.
Thereafter, EPA chose not to comment
or otherwise participate in Basin
Electric’s appeal and never informed the
parties or the Environmental Quality
Council that EPA considered
Wyoming’s BART decision to violate the
CAA. In fact, no contention was made,
by any person or entity, that the BART
permit issued by Wyoming violated the
CAA.
After litigation, Basin Electric’s
appeal was settled. Wyoming agreed to
remove the provision related to future
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control strategies in exchange for Basin
Electric’s agreement to reduce emission
levels further than those proposed in the
original permit and provide even further
reductions by the end of 2017. This
proposed settlement was presented to
the Environmental Quality Council for
approval. No persons or entities
objected to the proposed settlement,
including EPA.
Only after Wyoming’s regional haze
SIP was submitted to EPA did EPA
announce that it found the settlement
‘‘unreasonable’’ and something with
which it ‘‘disagreed.’’ Based upon these
assertions, and without demonstrating
that the BART permit actually violates
the CAA, EPA now proposes to void all
of the extensive administrative
proceedings, processes, comment
periods and permit finality accorded
under state law.
This violates the explicit
representations EPA made to the United
States Supreme Court that decisions to
over-ride state technology choices are
rarely undertaken and therefore do not
pose a threat to state adjudicative
processes. In footnote 14 of the ADEC
decision, the Court quoted EPA for the
proposition that EPA has engaged in
‘‘restrained and moderate’’ use of its
authority to overrule specific technology
choices and has never ‘‘asserted
authority to override a state-court
judgment.’’ Based upon this
understanding, the majority in ADEC
dismissed concerns expressed by the
dissent about state/federal relations,
stating that ‘‘[e]xperience . . . affords
no grounding for the dissent’s
predictions that EPA oversight . . . will
‘rewor[k] . . . the balance between State
and Federal Governments’ and threaten
state courts’ independence.’’ ADEC, 540
U.S. at 493 n. 16. With its proposed
action here, however, EPA is doing
precisely what the dissent in ADEC
predicted, ignoring the extended
contested case process afforded under
state law and the final administrative
litigation resolution reached under state
law.
While Basin Electric’s appeal ended
short of a court proceeding, the
distinction between a litigated judgment
in an administrative appeal and a
judgment in a state court proceeding is
not significant. In both cases, EPA’s
proposed action fails to respect the
cooperative federalism that underlies
the CAA in general. Under the RHR
deference to state authority is far more
compelling than issues related to public
health under the BACT program, and so
the Supreme Court’s holding in ADEC
that EPA may not require ‘‘recourse to
state processes’’ is inapplicable to BART
decisions. ADEC, 541 U.S. at 492. EPA
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should conduct itself in accordance
with the spirit of its representation to
the Supreme Court that it has never
sought to override a state-court
judgment, and should not attempt to
override a state BART decision that has
been litigated to an administrative
conclusion under state law particularly
where, as here, EPA never advised the
state adjudicators or the parties to the
state proceedings that it considered the
permit to be invalid under the CAA.
EPA could have participated in the State
administrative appeal proceeding or at a
minimum appeared therein to register
an objection to the settlement
agreement. Having elected not to do so,
EPA should respect the result of the
State’s process.
Response: EPA disagrees with this
comment. As an initial matter, as
provided in detail elsewhere in this
section and in the docket for this action,
we provided feedback to the State in our
comment letters on the proposed SIP
and in meeting with State and company
officials; therefore, the State and
companies were aware of our
expectations.
That WAQSR Chapter 6, Section 2 has
been approved into the SIP does not
somehow commit EPA to participate in
Wyoming’s BART permit process. The
Act and the RHR do not require that
BART be determined through a permit
process that is subject to administrative
appeal or through a permit process at
all. The SIP-approved provision in
Chapter 6, Section 2 for notice to EPA
of permit actions meets the
requirements of 40 CFR 51.161(d),
regarding public procedures for review
of new or modified sources, not BART
sources. Furthermore, nothing in
Chapter 6, Section 2 suggests that notice
to EPA of a permit process somehow
binds EPA to participate in that process.
The commenter provides no statutory,
regulatory, or judicial authority to
support the proposition that EPA must
participate in state administrative or
judicial procedures. With respect to
state judicial procedures, the Supreme
Court has stated: ‘‘[i]t would be unusual,
to say the least, for Congress to remit a
federal agency enforcing federal law
solely to state court.’’ Alaska Dep’t of
Envtl. Conservation v. EPA, 540 U.S.
461, 493 (2004). Thus the Court
‘‘decline[d] to read such an uncommon
regime into the [CAA].’’ Id. The
commenter’s notion that the ADEC
opinion (which concerned a BACT
determination under the PSD program)
is inapplicable to BART determinations,
merely because BART determination are
part of a program to improve visibility
rather than public health, finds no
support in the ADEC opinion or
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anywhere in the CAA. We elsewhere
respond to comments that argue that the
language of the CAA itself requires a
greater level of deference to states BART
determinations.
With respect to the dissent in ADEC,
that dissent of course does not represent
the opinion of the Supreme Court.
Nonetheless, EPA is not undoing the
State’s process through the ‘‘mere stroke
of a pen on the Agency’s letterhead,’’
but instead is acting on the State’s
regional haze submittal through noticeand-comment rulemaking that is
potentially subject to judicial review.
Furthermore, EPA is not confusing the
CAA with the APA; our authority and
duty to review the State’s regional haze
SIP for compliance with the CAA and
the RHR stems from the CAA itself. As
we discuss elsewhere, EPA’s role in
reviewing SIPs differs in many key
aspects from that of a court reviewing
agency action under the APA.
Under the CAA, states are required to
submit SIPS that contain emissions
limits necessary to protect visibility,
and EPA is required to disapprove of
any inadequate SIPs and promulgate
FIPs in their place. 42 U.S.C. 7491(b)(2);
Section 7410(c)(1)(A). The CAA does
not require EPA to participate in state
proceedings related to its SIP
submission, nor does it preclude EPA
from carrying out its statutory duty to
disapprove an inadequate SIP if EPA
does not participate in state
proceedings. The notion that BART
determinations are insulated from EPA
review simply because the State has an
administrative appeal process not only
has no support in the Act, it is contrary
to the purposes of the Act and EPA’s
express obligation to approve only SIP
submittals that meet the requirements of
the Act.
Moreover, any state BART decisions
made under an unapproved SIP are not
federally enforceable because any SIP
‘‘shall not be treated as meeting the
requirements of this chapter until the
Administrator approves the entire plan
revision as complying with the
applicable requirements.’’ 42 U.S.C.
7410(k)(3); see also Gen. Motors Corp. v.
United States, 496 U.S. 530, 540 (1990)
(holding EPA may bring enforcement
action under an existing SIP while a SIP
proposal is pending).
Finally, this action does not violate
the Tenth Amendment. The Supreme
Court has explained that ‘‘where
Congress has the authority to regulate
private activity under the Commerce
Clause, we have recognized Congress’
power to offer States the choice of
regulating that activity according to
federal standards or having state law
pre-empted by federal regulation.’’ New
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York v. United States, 505 U.S. 144, 167
(1992); see also U.S. Const. Art. I,
Section 8, cl. 3 (commerce clause); id.
Art. VI, cl. 2 (supremacy clause). The
commenter does not argue that the CAA
is outside of Congress’ Commerce
Clause authority. Through the SIP/FIP
mechanism, the Act offered Wyoming
the choice of regulating sources in the
State in accordance with the regional
haze provisions in the CAA and with
rules promulgated by EPA under its
CAA authority; thus the Act itself does
not violate the Tenth Amendment. With
respect to this particular action, our
disapproval of Wyoming’s regional haze
SIP and our FIP compel no action on the
part of the State and are not coercive
vis-a-vis the State. As explained
elsewhere in these responses, EPA has
not required Wyoming to adopt specific
control measures. Instead, our FIP
contains requirements applicable only
to some private companies. The Tenth
Amendment is not implicated by our
action.
Comment: Even if EPA can
contravene the state process, it should
still require compelling circumstances
demonstrating a plain and unambiguous
violation of the CAA before it
countermands a state proceeding. Such
a showing is necessary to preserve the
balance between Federal and state
governments under the CAA. EPA is
undermining the significance and
integrity of the State appeals process as
well as the State’s authority to
determine BART. EPA is also making it
possible for interested parties, including
environmental groups, to ignore their
procedural obligation to voice
objections under State law because they
can wait to raise them when EPA acts
on a proposed SIP. EPA chose not to
participate in the BART permit process
and the resulting appeals, despite
knowing that the very NOX control
equipment at issue in the regional haze
FIP was being determined. Under the
principles of comity, EPA should be
barred from now addressing these issues
at this late period. Under these
circumstances, EPA should not be
allowed to raise complaints with a
BART permit for the first time in the
federal proceeding. Failure to do so
diminishes State law and puts parties
like Basin Electric into a position where
they must pursue State remedies to
avoid finality under State law but find
that such actions mean nothing in the
end under the federal process.
Response: EPA disagrees with this
comment. Nothing in the CAA sets some
sort of ‘‘compelling circumstance’’
standard for disapproval of a SIP.
Instead, we have the duty to ensure that
regional haze SIP submittals meet the
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requirements of the Act and the RHR.
See CAA Section 110(a)(2)(J) (SIP
submittals must meet applicable
requirements of Part C of title I,
including visibility protection). We do
not agree that we are prohibited from
identifying deficiencies in the Wyoming
SIP after the State rulemaking process is
complete, and the commenter cites
nothing in the Act to the contrary.
Furthermore, many of the concerns
raised in this action were
communicated to the State in our
comment letters and in numerous
meetings with State officials. With
respect to comments we have received
from environmental organizations on
our proposed action on Wyoming’s SIP,
the CAA does not require those
organizations to participate in state
processes.34 EPA is taking actions
specified under the CAA in partially
approving and partially disapproving
the Wyoming SIP. The CAA also
specifies the responsibility of EPA to
issue a FIP when states have not met
their requirements under the CAA. EPA
is promulgating this FIP to fill the
regulatory gap created by the partial
disapproval. Under the FIP, the State
retains its authority to submit future
regional haze SIPs consistent with CAA
and RHR requirements; we do not
discount the possibility of a future,
approvable SIP submission that results
in the modification or withdrawal of the
FIP. This rulemaking does not change
the distribution of power between the
states and EPA.
Comment: BART applies to specific
emission sources and requires
consideration of facts applicable to
specific source locations. Unlike a rule,
or a SIP generally, a BART
determination effectively adjudicates
the specific rights and legal obligations
of individual emissions sources. This
typically entitles individual source
owners to substantive procedural rights
and remedies under state law when a
BART determination is made. In
Wyoming, for example, each individual
source is required to apply for a BART
Permit. Wyoming law affords the source
being regulated with special
opportunities to be heard, both as part
of the public review of a permit
application and, in the case of a permit,
in an adjudicative hearing with
opportunities to challenge factual
determinations, call and question
witnesses, and present evidence. When
an applicant applies for a BART
construction permit, the applicant is
34 In contrast, elsewhere in the Act Congress has
made it explicit that participation in state processes
is required in order to raise objections with EPA.
See CAA section 504(b)(2).
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5069
afforded the opportunity to present its
own views and responses to comments
to the state agency. If a permit is issued
or denied, the applicant can appeal the
permit decision to the Environmental
Quality Council, which has statutory
authority to amend, grant, modify, or
deny the permit. Wyo. Stat. Section 35–
11–802. This proceeding is conducted
as a contested case, affording the
applicant the right to cross-examine the
Environmental Quality Council’s
technical experts regarding their BART
assumptions and conclusions.
The applicant also can call its own
experts and witnesses. Wyo. Dep’t of
Envtl. Quality Rules and Regulations,
Wyo. Admin. Code ENV PP Ch. 2
Sections 1–14. With these procedures,
BART permit applicants can challenge
the cost estimates and assumptions
underlying a BART permit decision,
including making a showing, as Basin
Electric does here by comment only,
that EPA’s consultants have ignored
critical site-specific conditions.
EPA’s effort to impose BART
determinations by federal rulemaking
impermissibly deprives source owners
of these substantive procedural rights
afforded under State law. This is one
reason courts have taken a strong stance
against EPA imposing specific control
technologies through partial approval of
a SIP. Leaving site-specific decisions in
the hands of the states provides statesponsored procedural rights for the
individually regulated sources. See
Virginia, 108 F.3d at 1406–10; Michigan
v. Thomas, 805 F.2d 176, 186 (6th Cir.
1986); Bethlehem Steel Corp., 742 F.2d
at 1035–37 (all holding that EPA may
not render a state SIP more stringent
than intended by the state by partial SIP
approval or imposition of control
technologies). A BART determination
requires consideration of complex, casespecific control technologies and makes
fact-dependent determinations for
individual named sources, which
effectively makes the federal BART
determination an administrative order
directed specifically at Basin Electric
rather than a rule generally applicable to
the public. Under these circumstances,
EPA cannot order specific emission
limits and consequent expensive control
technologies without affording Basin
Electric a hearing at which it can cross
examine EPA’s consultants. Basin
Electric must also be given an
opportunity to challenge EPA’s
interpretation of the facts. When EPA
moves from a quasi-legislative function
to a quasi-judicial function, as it has by
making fact-based determinations for
specific, named sources, it must provide
the required procedural protections for
those affected by its actions. See
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Londoner v. City & Cnty. of Denver, 210
U.S. 373, 386 (1908) (requiring an
agency to provide notice and an
adjudicative hearing for individuals
suffering specific injury from an agency
rule); compare Amoco Oil Co. v. EPA,
501 F.2d 722, 734–35 (D.C. Cir. 1974)
(agency action was quasi-legislative
because it did not rely on ‘‘findings of
fact’’ and evidence to make
determinations for a single source).
One administrative law expert
designated the distinction between rule
making and adjudication as ‘‘perhaps
the most critical distinction in all of
administrative law.’’ Gary Lawson,
Federal Administrative Law 10
(American Casebook Series, ThomsonWest 4th ed. 2007). It is an important
distinction because it separates agency
decisions that function as policy from
those that make situational
determinations. ‘‘A plain[ ] instance of
administrative adjudication occurs
where an administrative agency at one
and the same time makes a rule and
applies it to a concrete situation . . .
The essential difference between
legislation and adjudication is not that
one looks to the future and the other to
the past . . . What distinguishes
legislation from adjudication is that the
former affects the rights of individuals
in the abstract and must be applied in
a further proceeding before the legal
position of any particular individual
will be definitely touched by it; while
adjudication operates concretely upon
individuals in their individual
capacity.’’ John Dickinson,
Administrative Justice and the
Supremacy of Law in the United States
16–21 (Harvard University Press 1927),
quoted in Gary Lawson, Federal
Administrative Law 10–11(American
Casebook Series, Thomson-West 4th ed.
2007).
In the Proposed Rule, EPA makes
specific factual findings about
individual sources. EPA relies on its
expert consultant Andover to draw
specific factual conclusions about
retrofit construction costs for Laramie
River, yet it affords Basin Electric no
opportunity to confront its expert over
the Andover Report’s error-filled
findings. In order to provide due
process, a specific party like Basin
Electric who is singled out and
subjected to EPA’s fact-based
determinations must be allowed ‘‘the
right to support his allegations by
argument however brief[,] and, if need
be, by proof, however informal.’’
Londoner, 210 U.S. at 386. In the case
of Laramie River, the requirement for a
hearing is especially strong because
‘‘[t]he extent to which procedural due
process must be afforded the recipient is
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influenced by the extent to which he
may be ‘condemned to suffer grievous
loss.’ ’’ Goldberg v. Kelly, 397 U.S. 254,
262–63 (1970) (citing Joint Anti-Fascist
Refugee Comm. v. McGrath, 341 U.S.
123, 168 (1951)).
EPA must afford these procedural
rights to Basin Electric if EPA is going
to assume control over site-specific
BART determinations, rather than leave
them to the states as Congress intended.
Section 169A’s directive that BART be
determined by the states permits states
to afford individual emissions sources
the procedural and other rights that due
process requires for site-specific
regulation, and EPA must afford these
same rights to source owners if it is
going to federalize the BART program
by rejecting all state determinations
with which its technical consultants
disagree.
Response: EPA disagrees with this
comment. EPA’s procedures did not
deprive Basin Electric of due process.
First, the comment confuses the issues
by arguing that under State law Basin
Electric has ‘‘substantive procedural
rights’’ and that EPA’s procedures
somehow deprived Basin Electric of
these. But due process under the Fifth
Amendment does not require EPA to
give exactly the same process that the
State gave. The commenter provides no
authority for the existence of something
called a state ‘‘substantive procedural
right’’ that the United States is bound by
the Fifth Amendment to respect.35
Instead, federal due process protects
substantive fundamental rights and
procedural rights if the claimant has a
constitutionally protected life, liberty,
or property interest. See U.S. Const.,
Amend. V (‘‘nor be deprived of life,
35 The cases cited by the commenter, Virginia,
108 F.3d at 1406–10; Michigan v. Thomas, 805 F.2d
176, 186 (6th Cir. 1986); Bethlehem Steel Corp., 742
F.2d at 1035–37, lack any reference to a notion of
‘‘state substantive procedural rights’’ or ‘‘statesponsored procedural rights.’’ The opinion in
Virginia concerns the roles EPA and states play
under the Act; the opinion does not discuss due
process for owners of individual sources. The
opinion in Michigan, noting that EPA’s action had
a rational basis, briefly dismisses a claim that the
action violated the due process clause of the Fifth
Amendment by discriminating against business and
industry. Michigan, 805 F.2d at 185 n.1. Although
the opinion does not make it explicit, the claim
there thus seems to have been equal protection as
incorporated into the Fifth Amendment, not
procedural due process. See Bolling v. Sharpe, 347
U.S. 497 (1954). Michigan is not on point. Finally,
the dicta in Bethlehem Steel speculates that, in the
case of a FIP, ‘‘EPA might have had to give
interested persons an opportunity to submit oral as
well as written comments,’’ Bethlehem Steel, 742
F.2d at 1032, which EPA did in this case. The dicta,
which in any case is not binding, does not say that
EPA’s experts must be available for crossexamination or that EPA is bound by state
procedures or that the Fifth Amendment to the U.S.
Constitution recognizes state ‘‘substantive
procedural rights.’’
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liberty, or property, without due process
of law’’). That the comment attempts to
make a state procedure into a
constitutionally protected interest by
calling it a ‘‘substantive procedural
right’’ is of no avail; the comment
identifies no attribute of the state
procedure that makes it into a
constitutionally protected ‘‘life, liberty,
or property’’ interest under either the
text of the Fifth Amendment or the case
law interpreting that Amendment. See
Cleveland Bd. Of Educ. v. Loudermill,
470 U.S. 532, 541 (1985) (‘‘[T]he Due
Process Clause provides that certain
substantive rights—life, liberty, and
property—cannot be deprived except
pursuant to constitutionally adequate
procedures. The categories of substance
and procedure are distinct.’’). Nor does
Basin Electric have a protected interest
in the outcome of the State BART
permit process. There is no ‘‘legitimate
claim of entitlement’’ to that outcome,
Board of Regents of State Colleges v.
Roth, 408 U.S. 564, 577 (1972), as the
State’s BART determination was always
subject to review by EPA under the
CAA. In the end, what the Fifth
Amendment does potentially protect is
Basin Electric’s property interest itself,
not the State procedure. As we now
explain, EPA’s procedures were
sufficient to satisfy the requirements of
due process with respect to Basin
Electric’s property interest.
CAA section 307(d) specifies the
procedures that EPA is required to
follow in promulgating a FIP. Section
307(d) does not require adjudicatory
hearings, nor does it require EPA to
allow for cross-examination of EPA’s
consultants.36 Additionally, the
Administrative Procedure Act only
requires adjudicatory hearings if a
particular statute specifies that a rule
must be made ‘‘on the record after an
opportunity for an agency hearing.’’ 37
No such requirement is contained in
section 307(d).38 The Supreme Court
has explained that courts face an
extremely high burden in order to
impose additional procedures beyond
those specifically required by statute
because ‘‘unwarranted judicial
examination of perceived procedural
shortcomings of a rulemaking
proceeding can do nothing but seriously
interfere with that process prescribed by
Congress.’’ 39 EPA followed the
36 See
42 U.S.C. 7607(d)(5).
5 U.S.C. 553(c); see also U.S. v. AlleghenyLudlum Steel Corp., 406 U.S. 742, 757 (1972).
38 See 42 U.S.C. 7607(d)(5); see also Anaconda
Co. v. Ruckelshaus, 482 F.2d 1301, 1306 (10th Cir.
1973).
39 Vermont Yankee Nuclear Power Corp. v.
Natural Res. Def. Council, Inc., 435 U.S. 519, 548
(1978).
37 See
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procedures required by Congress in the
CAA and EPA believes that no
additional proceedings are warranted.
Moreover, Congress specifically
contemplated and rejected a crossexamination requirement for public
hearings in section 307.40 The House
bill contained an opportunity to crossexamine those who made oral
presentations at the public hearing.
During Conference Committee, this was
deleted and replaced with a requirement
that the rulemaking record remain open
for thirty days after public hearing to
allow interested parties to submit
rebuttal and supplemental
information.41
The comment cites Goldberg v. Kelly,
397 U.S. 254, 262–63 (1970) and argues
that Basin Electric, like the welfare
recipient in Goldberg, has an especially
strong claim to an evidentiary hearing
prior to EPA’s final rulemaking because
Basin Electric may be ‘‘condemned to
suffer grievous loss.’’ The comment fails
to explain why the private interest of
Basin Electric here is identical to the
Goldberg welfare recipient’s private
interest in an evidentiary hearing before
the termination of welfare benefits. The
comment also does not examine the
factors set out in Mathew v. Eldridge,
424 U.S. 319 (1976),42 for determining
what due process requires, and so does
not provide any reason for EPA to think
that the procedures here were
inadequate. In particular, the comment
provides no basis to think that EPA’s
procedures created a serious ‘‘risk of an
erroneous deprivation’’ of Basin
Electric’s interest and that there would
be any ‘‘probable value’’ to crossexamination. With respect to the alleged
errors referred to in the comment, Basin
Electric has made its arguments as to
why they are errors and EPA has
responded why they are not. If Basin
Electric thinks EPA’s responses are
inadequate, then Basin Electric may
seek judicial review of EPA’s action
under section 307(b) of the Act. The risk
of erroneous deprivation appears small,
and Basin Electric’s comment gives no
reason to think otherwise. Basin
Electric’s comment also does not
40 Kennecott Corp. v. EPA, 684 F.2d 1007, 1020
(D.C. Cir. 1982).
41 See H.R. Rep. No.95–564, 95th Cong. (1977).
42 ‘‘[I]dentification of the specific dictates of due
process generally requires consideration of three
distinct factors: First, the private interest that will
be affected by the official action; second, the risk
of an erroneous deprivation of such interest through
the procedures used, and the probable value, if any,
of additional or substitute procedural safeguards;
and finally, the Government’s interest, including
the function involved and the fiscal and
administrative burdens that the additional or
substitute procedural requirement would entail.’’
Eldridge, 424 U.S. at 335.
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identify any particular value to crossexamination in this context. As the
comment admits, the matters here are
ones of technical judgment; they are not
(for example) eyewitness accounts that
might benefit from cross-examination.
EPA also notes that the comment fails
to discuss ‘‘the Government’s interest,
including . . . the fiscal and
administrative burdens’’ that crossexamination would entail. Eldridge
alternatively identified this third factor
as ‘‘the public interest.’’ Eldridge, 424
U.S. at 347. In considering the burdens
imposed by a full adjudicatory hearing
on the Government and the public, the
Tenth Circuit Court of Appeals stated
(albeit before Eldridge, so not in the
context of applying the Eldridge factors):
Unending procedure could be produced by
an adjudicatory hearing. This could bring
about unending delay which would not only
impede but completely stifle congressional
policy. We do not, of course, condemn the
trial court’s concern for the rights of [the
petitioner]. Those rights are important and
the court should be sensitive to them, but
those rights are not of such magnitude as to
overcome congressional policy and the rights
of the remainder of the community.
Anaconda Co. v. Ruckelshaus, 482 F.2d
1301, 1307 (10th Cir. 1973). The
comment gives EPA no reason to think
otherwise.
With respect to the comment’s
invocation of the BiMetallic-Londoner
distinction between rulemaking and
adjudication, it is not clear that
Londoner applies here, where the
interests of many parties are at stake.
See Anaconda, 482 F.2d at 1306 (‘‘The
fact that Anaconda alone is involved is
not conclusive on the question as to
whether the hearing should be
adjudicatory, for there are many other
interested parties and groups who are
affected and are entitled to be heard. So
the guidelines enunciated by Mr. Justice
Holmes in Bi-Metallic Investment Co. v.
State Board of Equalization are not
applicable.’’) (citation omitted). Even if
the distinction does apply, due process
does not per se require a full
adjudicatory hearing. As the comment
admits, what due process does require
is that a person ‘‘have the right to
support his allegations by argument,
however brief: and, if need be, by proof,
however informal.’’ Londoner v. City &
Cnty. of Denver, 210 U.S. 373, 386
(1908). Thus the ‘‘core of due process is
the right to notice and a meaningful
opportunity to be heard.’’ 43 With
respect to whether a full evidentiary
hearing is required, ‘‘differences in the
origin and function of administrative
agencies preclude wholesale
43 LaChance
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5071
transplantation of the rules of
procedure, trial, and review which have
evolved from the history and experience
of courts. The judicial model of an
evidentiary hearing is neither a
required, nor even the most effective,
method of decision making in all
circumstances.’’ Eldridge, 424 U.S. at
348 (citations and quotations omitted).
EPA believes Basin Electric was
afforded a meaningful opportunity to be
heard and present evidence to EPA in
support of its position. EPA notified the
public of its proposed rule, held a
public hearing, and accepted public
comments for a period of 60 days.44 In
an effort to provide a greater
opportunity for public comment on the
proposed rule, EPA held two additional
public hearings and extended the
comment period to 75 days, which goes
beyond the procedures required by the
CAA. 45 Basin Electric submitted
extensive comments prior to the first
comment deadline, participated in two
public hearings, and submitted
additional comments during the
extended public comment period.46
Basin Electric took full advantage of its
opportunity to be heard and was not
denied due process.
Comment: Section 169A requires the
State to take into consideration five
different factors when making its BART
determination. 43 U.S.C. 7491(g)(2). But
these factors ‘‘were meant to be
considered together’’ to arrive at a single
judgment committed to the State: A
BART emission limit. American Corn
Growers, 291 F.3d at 6. Moreover, only
Wyoming—not EPA—is entitled to
determine the weight and significance
to assign costs, feasibility, and visibility
improvements. 70 FR 39123 (‘‘The State
makes a BART determination based on
the estimates available for each
criterion, and as the CAA does not
44 Implementation Plans; Approvals,
Disapprovals and Promulgations: Wyoming;
Regional Haze State Implementation Plan; Federal
Implementation Plan for Regional Haze June 10,
2013 Docket EPA–R08–OAR–2012–0026–0093.
45 Air Quality State Implementation Plans;
Approvals, Disapprovals and Promulgations:
Wyoming; Regional Haze State Implementation
Plan; Federal Implementation Plan for Regional
Haze; Public Hearings Jul. 8, 2013 Docket EPA–
R08–OAR–2012–0026–0098; see 42 U.S.C.
7607(d)(5).
46 Basin Electric Power Cooperative Comments,
Aug. 6, 2013 Docket EPA–R08–OAR–2012–0026–
0058; Public Comment from Basin Electric Email
Aug. 9, 2013 Docket EPA–R08–OAR–2012–0026–
0148; Transcript from July 26, 2013 Hearings in
Casper, Wyoming Aug. 8, 2013 Docket EPA–R08–
OAR–2012–0026–0108 pp. 48–83; Transcript from
June 24, 2013 Hearings in Cheyenne, Wyoming
Aug. 15, 2013 Docket EPA–R08–OAR–2012–0026–
0100 pp. 62–67; Additional Public Comment from
Basin Electric Laramie River Station BART
CALPUFF Modeling Analysis Aug. 26, 2013 Docket
EPA–R08–OAR–2012–0026–0227.
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specify how the State should take these
factors into account, the States are free
to determine the weight and
significance to be assigned to each
factor.’’); see also 40 CFR Part 51, App.
Y, Section IV.D.5.
By applying a different assessment of
costs and visibility than those employed
by Wyoming in its BART determination,
and assuming that these assessments
mandate a different BART outcome,
EPA’s proposed FIP rejects the State’s
determinations on cost, feasibility, and
visibility improvement without
considering whether, taken together, the
five statutory factors would compel a
different result than the one reached by
Wyoming. The net result is a decision
imposing a different BART choice than
that selected by the State by splitting the
statutory factors and giving them
separate and independent determinative
significance—the same legal error EPA
made in American Corn Growers. The
‘‘splitting of the statutory factors is
consistent with neither the text nor the
structure of the statute.’’ 291 F.3d at 6.
Wyoming must therefore be afforded
an opportunity to reconsider its BART
determination before EPA imposes a
FIP. This is necessary to preserve State
primacy in the BART determination.
States ‘‘determine what is too costly
(and what is not) for a particular
source.’’ Am. Corn Growers, 291 F.3d at
6–7. The actual BART determination
flows not from any one of the statutory
factors, but instead from consideration
of all of them together. That is why it
is erroneous for EPA to impose its own
BART choice without explaining how it
reached that choice upon consideration
of all five statutory factors. If EPA acts
to correct alleged errors in the State’s
cost assessment or visibility modeling,
EPA must remand the statutory
evaluation back to the State. Section
110(c) contemplates that States should
be given an opportunity to correct any
‘‘deficiencies,’’ and this statutory
opportunity should not be taken from
the State as a result of self-imposed
consent decree deadlines. Doing so
destroys State primacy in the BART
determination.
It also results in a BART
determination from EPA that is not
informed and explained by an
independent assessment of the five
statutory factors. EPA’s failure to
remand the BART determination back to
the State therefore results in neither the
State nor EPA making a BART
assessment that considers all of the
statutory factors together. While Basin
Electric acknowledges that the Tenth
Circuit Court of Appeals recently
reached a different conclusion in
Oklahoma v. EPA, 723 F.3d 1201 (10th
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Cir. 2013), that case is not yet final and
that Court was not presented with, and
did not consider, the fundamental
problem associated with EPA’s effort to
make one of the five statutory factors
outcome determinative. EPA cannot
cause an outcome in which no agency
has actually complied with the statute,
which is what happens when EPA
simultaneously disapproves the State’s
BART assessment on one or two
statutory factors and then imposes a
different BART assessment based upon
cost and visibility factors combined
with the State’s prior consideration of
the other factors, as EPA does here. This
is not a procedural error, but rather an
error that results in no agency—neither
the State nor EPA—actually complying
with the statute by considering all five
statutory factors together before arriving
at a BART emission limit.
Response: EPA does not agree with
this comment. The RHR and the BART
Guidelines allow the reviewing
authority (State, Tribe, or EPA) the
discretion to determine how to weigh
and in what order to evaluate the
statutory factors (cost of compliance, the
energy and non-air quality
environmental impacts of compliance,
any existing pollution control
technology in use at the source, the
remaining useful life of the source, and
the degree of improvement in visibility
which may reasonably be anticipated to
result from the use of such technology),
as long as the reviewing authority
justifies its selection of the ‘‘best’’ level
of control and explains the CAA factors
that led the reviewing authority to
choose that option over other control
levels.47 In this action, having
disapproved the State’s BART
determinations for NOX at five units,
‘‘all of the rights and duties that would
otherwise fall to the State accrue instead
to EPA.’’ 48 This includes a significant
degree of discretion in deciding how to
weigh the five factors, so long as that
weighing is accompanied by reasoned
explanation for adopting the technology
selected as BART, based on the five
factors, and in accordance with the
BART Guidelines. EPA has provided a
detailed explanation of our BART
evaluation process and five-factor
analyses in our proposal, and elsewhere
in this final notice. We have weighed
the potential energy and non-air
environmental quality impacts of the
various control options along with the
other statutory factors in our BART
analyses. We have not, as the
47 See BART Guidelines, 40 CFR Part 51,
appendix Y, section IV.E.2.
48 Central Arizona Water Conservation Dist. v.
EPA, 990 F.2d 1531, 1541 (9th Cir. 1993).
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commenter surmises, approved the
State’s assessment of certain factors and
disapproved the assessment of others,
replacing just the factors we have
disapproved. Instead, for those NOX
BART determinations we are
disapproving, we have disapproved
them in their entirety. Then EPA
independently assessed and weighed
the five factors. That we adopted the
State’s assessment of certain factors as
our own does not change this. Thus the
split in authority that the commenter
suggests simply has not occurred.
We also disagree that our proposal is
inconsistent with the American Corn
Growers decision. In American Corn
Growers, the petitioners challenged the
original RHR because, among other
things, the RHR treated one of the five
statutory factors differently than the
others by requiring states to consider the
degree of visibility improvement from
imposing BART on a group of sources
rather than on a source-specific basis.49
The court concluded that such a
requirement could force states to apply
BART controls at sources without
evidence that the individual sources
contributed to visibility impairment at a
Class I area, which encroached on
states’ primary authority under the
regional haze provisions to determine
which individual sources are subject to
BART and what BART controls are
appropriate for each source.50
Therefore, the court vacated the
visibility improvement part of the
original RHR as contrary to the statute.51
Contrary to some commenters’
suggestions, however, the American
Corn Growers decision did not address
EPA’s authority to reject a state’s BART
determinations for failure to conform to
the CAA, the RHR, or the BART
Guidelines.
Finally, as explained elsewhere in
this final rule, we have the authority to
promulgate a FIP concurrently with a
disapproval action.
Comment: EPA’s FIP is subject to
APA review. Accordingly, it cannot
withstand judicial scrutiny if it is
arbitrary, capricious, an abuse of
discretion, or not in accordance with the
law. See 5 U.S.C. 706(2)(A); Olenhouse,
42 F.3d at 1574. More generally, a court
will set it aside ‘‘if the agency relied on
factors which Congress has not intended
for it to consider, entirely failed to
49 291
F.3d at 5–9.
at 7–8.
51 EPA revised the RHR to address the court’s
decision in American Corn Growers at the same
time as we promulgated the BART Guidelines. 70
FR 39104 (July 6, 2005). The revised RHR and the
Guidelines were upheld by the D.C. Circuit in
Utility Air Regulatory Group v. EPA, 471 F.3d 1333
(D.C. Cir. 2006).
50 Id.
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consider an important aspect of the
problem, offered an explanation for its
decision that runs counter to the
evidence before the agency, or is so
implausible that it could not be ascribed
to a difference in view or the product of
agency expertise.’’ State Farm, 463 U.S.
at 43.
A court reviewing agency action
under the APA must ‘‘ascertain whether
the agency examined the relevant data
and articulated a rational connection
between the facts found and the
decision made.’’ Olenhouse, 42 F.3d at
1574 (citing State Farm, 463 U.S. at 43)
(footnote omitted). A reviewing court
also must review the agency’s
explanation to ‘‘determine whether the
agency considered all relevant factors
and whether there has been a clear error
of judgment.’’ Id. (citing, inter alia,
Citizens to Preserve Overton Park, Inc.
v. Volpe, 401 U.S. 402, 416 (1971)). The
court ‘‘‘should not attempt itself to make
up for . . . deficiencies’’’ in the
agency’s reasoning and ‘‘may not supply
a reasoned basis for the agency’s action
that the agency itself has not given.’’ Id.
at 1574–75 (quoting State Farm, 463
U.S. at 43) (emphasis removed).
As a result, ‘‘‘an agency’s action must
be upheld, if at all, on the basis
articulated by the agency itself,’’ and
‘‘the grounds upon which the agency
acted must be clearly disclosed in, and
sustained by, the record.’’ Id. at 1575
(quoting State Farm, 463 U.S. at 50). In
its decision, ‘‘[t]he agency must make
plain its course of inquiry, its analysis
and its reasoning.’’ Id. Moreover, its
action must be ‘‘supported by the facts
in the record.’’ Id. This means the action
must be supported by ‘‘substantial
evidence,’’ i.e., ‘‘‘enough to justify, if the
trial were to a jury, a refusal to direct
a verdict when the conclusion to be
drawn is one of fact.’’’ Id. (citation
omitted). In addition to providing a
basis for invalidating the agency action,
an agency’s failure to fully explain and
support its reasoning warrants a court’s
grant of less deference to the agency’s
decisions. See, e.g., Achernar Broad. Co.
v. FCC, 62 F.3d 1441, 1447 (D.C. Cir.
1995) (‘‘no deference is due when the
agency has stopped shy of carefully
considering the disputed facts’’); NLRB
v. P*I*E Nationwide, Inc., 923 F.2d 506,
518 n.16 (7th Cir. 1991) (‘‘deference
given to an agency is not granted freely,
it is purchased; the agency must
exercise its touted expertise and
‘‘explain the rationale and factual basis
for its decision’’) (citation omitted).
Although a court generally will defer
to an agency’s experts when the agency
acts within its area of expertise, a court
will not do so and will invalidate the
agency’s action where its expert’s
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decisions were arbitrary and capricious.
See, e.g., Garvey, 256 F.3d at 1036
(agencies can rely on their own experts
only ‘‘so long as their decisions are not
arbitrary and capricious’’) (citation
omitted). See also NetCoalition v. SEC,
615 F.3d 525, 539 (D.C. Cir. 2010)
(‘‘[W]e do not defer to the agency’s
conclusory or unsupported
suppositions.’’) (citation omitted);
Brower v. Evans, 257 F.3d 1058, 1067
(9th Cir. 2001) (‘‘The deference
accorded to an agency’s scientific or
technical expertise is not unlimited. The
presumption of agency expertise can be
rebutted when its decisions, while
relying on scientific expertise, are not
reasoned.’’) (citation omitted); Nat.
Resources Defense Council, 725 F.2d at
768, 771 (the court owed EPA no
deference where the agency
‘‘complete[ly] fail[ed] to consider the
criteria that should inform [its
decision]’’). Similarly, an agency can
rely on a model ‘‘only so long as it
‘explains the assumptions and
methodology used in preparing the
model’ and ‘provides a complete
analytical defense’ should the model be
challenged.’’ Appalachian Power Co. v.
EPA, 249 F.3d 1032, 1052 (D.C. Cir.
2001) (citation and brackets omitted).
See also Sierra Club v. Costle, 657 F.2d
298, 333 (D.C. Cir. 1981) (although
computer modeling undoubtedly ‘‘is a
useful and often essential tool,’’ an
‘‘agency must sufficiently explain the
assumptions and methodology used in
preparing the model’’ and must
‘‘provide a complete analytic defense of
its model (and) respond to each
objection with a reasoned presentation’’)
(internal quotation marks omitted), rev’d
on other grounds, 463 U.S. 680 (1983);
id. (there must be ‘‘a rational connection
between the factual inputs, modeling
assumptions, modeling results and
conclusions drawn from these results’’).
Here, in promulgating its FIP, EPA was
required to do the same thing Wyoming
did: determine BART by ‘‘tak[ing] into
consideration’’ the five statutory factors,
including the costs of compliance, the
energy and non-air quality
environmental impacts of compliance,
any existing pollution control
technology in use at the source, the
remaining useful life of the source, and
the degree of improvement in visibility
that may reasonably be anticipated to
result from the use of the technology.
CAA Section 169A(g)(2), 42 U.S.C.
7491(g)(2). As the D.C. Circuit explained
in American Corn Growers, ‘‘the factors
were meant to be considered together’’
in determining BART, as ‘‘[t]he language
of section 169A(g)(2) can be read in no
other way.’’ 291 F.3d at 6.
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Accordingly, in order to comply with
the CAA and withstand APA review,
EPA must fully explain how it assessed
and weighed the five BART factors
together, and it must support that
explanation with record facts. EPA has
failed to do so. Additionally, the same
regulations EPA promulgates for state
BART determinations must also apply
to BART determinations made by EPA.
See CAA Section 169A(b)(2)(A), 42
U.S.C. 7491(b)(2)(A). Indeed, it would
be arbitrary and capricious for EPA to
require a state to follow certain specific
guidelines in making a BART
determination, yet to not itself follow
those same guidelines in making that
same determination after taking it out of
the state’s hands. Moreover, EPA has
suggested that the BART Guidelines and
Cost Manual are mandatory provisions
that must be followed in order to
comply with the CAA.
Response: We disagree with this
comment. As detailed elsewhere in this
document and documented in the
supporting record, EPA applied the
BART statutory factors and BART
Guidelines to each and every BART unit
that is covered under this rulemaking;
fully considered all significant
comments submitted on the proposed
notices and incorporated those
comments as appropriate; provided
basis for the decisions; applied models
that are specified in the BART
Guidelines (thus, the opportunity for
commenters to challenge the specified
models has long passed); developed and
provided detailed explanations
regarding EPA’s model inputs and
settings; and rationally applied the
modeling results to the final
determinations in applying the BART
and reasonable progress factors. The
comment does not identify any
deficiency in any portion of this.
Comment: Wyoming developed a SIP
that established reasonable progress
toward meeting the national goal for
regional haze as required under the
CAA Section 169A(a)(1). EPA’s
establishment of a 2064 goal and glide
path requires incremental visibility
improvement for successive planning
periods. EPA also clearly explains in
these requirements that the glide path
and 2064 target date are not binding.
This provides considerable latitude to
the individual states that are responsible
to develop a regional haze SIP that
makes reasonable progress in a way that
works to achieve the visibility goals
over time.
The State developed and submitted a
plan that would make substantial
progress in reducing haze at the affected
Class I areas. The State followed the
process in the EPA’s Regional Haze
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Guidelines, yet because it came to a
different conclusion than EPA, the plan
was rejected and replaced with EPA’s
FIP.
By rejecting the State’s reasonable
approach, EPA has ignored its own
requirements and guidance. EPA’s
issuance of a FIP not only ignores the
flexibility and authority granted the
State, it also ignores EPA’s guidance for
establishing reasonable control
requirements.
Response: EPA disagrees with this
comment. While the RHR does not
require states to achieve the URP, when
a state’s selected RPGs do not meet the
URP, the state must demonstrate, based
on the four reasonable progress factors,
that meeting the URP is not reasonable
and that the selected RPGs are
reasonable. 40 CFR 51.308(d)(1)(ii). As
discussed elsewhere, the State did not
appropriately consider the four
reasonable progress factors for Dave
Johnston Units 1 and 2, and to the
extent that the State relied on its BART
determinations to show reasonable
progress for those sources, we have
disapproved some of those BART
determinations. While the comment
states that EPA ‘‘ignored its own
requirements and guidance,’’ the
comment does not cite any particular
requirement that EPA purportedly
violated.
Comment: The EPA proposal is
deficient in large measure because the
EPA has identified what it views as
deficiencies in the Wyoming SIP and,
rather than ordering reconsideration of
all relevant factors with improved data,
has created a FIP that suffers from
analytical errors and arrogates the EPA’s
role in development and review of SIPs.
If the EPA was convinced Wyoming’s
cost estimates were in error, it should
have directed corrections, rather than
substituting other flawed data and its
own judgment. Indeed, it is apparent the
EPA is not committed to maintaining
the CAA’s deference to states’ authority
to formulate workable haze plans.
Otherwise, the EPA would have
required Wyoming to correct perceived
cost estimate errors and subsequently
reevaluate BART factors. The EPA
instead, substituted its own errors and
performed its own evaluation in pursuit
of its own goals.
Another commenter argued that EPA
should not impose a FIP until it has
issued a final rule disapproving the
Wyoming regional haze SIP. 42 U.S.C.
7410(c)(1)(B). EPA should first conduct
a rulemaking and take public comment
on the Wyoming regional haze SIP
submission, issue its determination on
the regional haze SIP, and then seek
input from the State. (See 42 U.S.C.
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7410(c)(1)(B); see also 42 U.S.C.
7607(d)(B) (rulemaking provisions apply
to ‘‘the promulgation or revision of an
implementation plan by the
Administrator under section 7410(c)’’)
Otherwise, EPA removes the State from
its assigned role as the one determining
BART.
The facts here illustrate this problem.
EPA initially agreed with Wyoming’s
BART determinations for Naughton
Units 1 and 2, and Dave Johnston Unit
3. EPA then reversed itself, supposedly
on the basis of new cost and visibility
information. Without offering Wyoming
any chance to review the new
information and issue a new BART
determination, EPA disapproved
Wyoming’s BART determination for
these units, and instituted new BART
determinations for these units through a
regional haze FIP. EPA’s failure to
provide Wyoming an opportunity to
review this new information, and
address it through a revised BART
determination, violates the applicable
CAA statutes.
The CAA defines a FIP as a plan (or
portion thereof) promulgated by the
(EPA) Administrator to fill all or a
portion of a gap or otherwise correct all
or a portion of an inadequacy in a SIP.
42 U.S.C. 7602(y). Until EPA first
assesses the Wyoming regional haze SIP,
develops a proposed rule to approve or
disapprove the Wyoming regional haze
SIP, solicits and receives public
comment on that proposed rule,
considers the comments and
information, and takes final action on
whether (and to what extent) to approve
the Wyoming SIP, EPA cannot know
whether there is a ‘‘gap’’ in the
Wyoming regional haze SIP that needs
to be filled or whether (and to what
extent) there is an ‘‘inadequacy’’ in the
Wyoming regional haze SIP that needs
to be corrected. Id. Moreover, EPA’s
failure to obtain public comments prior
to proposing a regional haze FIP
deprives Wyoming of an opportunity to
correct any ‘‘deficiencies’’ identified by
EPA. Here, where EPA claims to have
obtained new cost and visibility
information but did not allow Wyoming
an opportunity to review and act on the
new information, EPA’s final
determination regarding the Wyoming
regional haze SIP ignores the State’s
authority under the CAA (including the
regulatory programs implicated by CAA
Section169A) to design and implement
plans to control air pollution control
within its borders. (See 42 U.S.C.
7401(a)(3).) Therefore, EPA illegally
seeks to impose its regional haze FIP
and should withdraw the same.
Earlier comments argued that EPA
cannot impose a regional haze FIP until
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it has issued a final rule disapproving
Wyoming’s regional haze SIP. 42 U.S.C.
7410(c)(1)(B) mandates that disapproval
of all or part of a SIP is a prerequisite
to promulgation of a FIP. EPA must first
conduct a rulemaking and take public
comment on Wyoming’s regional haze
SIP submission, issue its determination
on the regional haze SIP, and then
proceed, or not, with promulgation of a
regional haze FIP. (See 42 U.S.C.
7410(c)(1)(B); see also 42 U.S.C.
7607(d)(B) (rulemaking provisions apply
to ‘‘the promulgation or revision of an
implementation plan by the
Administrator under section 7410(c)’’)
Response: We disagree with this
comment. We have the authority to
promulgate a FIP concurrently with a
disapproval action. Nowhere in the
CAA is there language that limits EPA’s
authority to simultaneously propose a
FIP and propose disapproval of a state’s
SIP where there has been a prior finding
of a failure to submit. This timing for
FIP promulgation is authorized under
CAA section 110(c)(1). As has been
noted in past FIP promulgation actions,
the language of CAA section 110(c)(1),
by its terms, establishes a two-year
period within which we must
promulgate the FIP, and provides no
further constraints on timing. See, e.g.,
76 FR 25178, at 25202. Wyoming failed
to submit the 40 CFR 51.309(g) plan
elements by December 17, 2007, as
required under the CAA and our
implementing regulations. Two years
later, Wyoming still had not submitted
these required plan elements. When we
made the finding in 2009 that Wyoming
had failed to submit these regional haze
SIP elements (see 74 FR 2392), that
created an obligation for us to
promulgate a FIP by January 2011. We
are exercising our discretion to
promulgate the FIP concurrently with
our disapproval action because of the
applicable statutory deadlines requiring
us at this time to promulgate regional
haze BART determinations to the extent
Wyoming’s BART determinations are
not approvable. In these concurrent SIP/
FIP actions, if comments or other
information cause us to reconsider
portions of our proposed disapproval,
and instead approve additional portions
of Wyoming’s SIP, we can readily adjust
our FIP accordingly by not finalizing the
FIP portions that are no longer needed,
as, indeed we are doing in this case.
Thus, the supposed procedural problem
the comment identifies simply does not
exist.
With respect to the argument that the
CAA requires EPA, before promulgating
a FIP, to give additional opportunities to
Wyoming to address the deficiencies
that EPA has identified, in fact the
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opposite is true. Under section 110(c)(1)
of the CAA, EPA must promulgate a FIP
within 2 years of a finding of failure to
submit a required SIP submittal. As
explained above, the requirement for a
FIP promulgation in today’s action was
triggered by a finding published on
January 15, 2009 (74 FR 2392), that
Wyoming (among other states) had
failed to make a submittal to address the
requirements of 40 CFR 51.309(g). Thus,
EPA had an obligation to promulgate a
FIP for the requirements of 40 CFR
51.309(g) by January 15, 2011, unless
the State submitted and EPA approved
a SIP addressing the deficiency.
Although we are approving portions of
Wyoming’s SIP that meet the
requirements of 51.309(g), we are
disapproving other portions and,
therefore, are still under an obligation to
promulgate a FIP for those portions. In
considering a similar argument to that
made by the commenter, the Tenth
Circuit Court of Appeals has stated:
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Once the EPA issued findings that
Oklahoma failed to submit the required SIP
under the Regional Haze Rule, the EPA had
an obligation to promulgate a FIP. The statute
itself makes clear that the mere filing of a SIP
by Oklahoma does not relieve the EPA of its
duty. And the petitioners do not point to any
language that requires the EPA to delay its
promulgation of a FIP until it rules on a
proposed SIP. As the EPA points out, such
a rule would essentially nullify any time
limits the EPA placed on states. States could
forestall the promulgation of a FIP by
submitting one inadequate SIP after another.
Oklahoma v. EPA, 723 F.3d 1201, 1223
(10th Cir. 2013).
Finally, as explained elsewhere,
under the FIP, the State retains its
authority to submit future regional haze
SIPs consistent with CAA and RHR
requirements; which may result in the
modification or withdrawal of the FIP.
Comment: The CAA and the RHR
provide substantial discretion to states
to determine how best to make
reasonable progress toward achieving
natural visibility conditions in
designated areas. Reasonable progress—
the touchstone of the regional haze
program—is a flexible benchmark. See
42 U.S.C. 7491(g)(1). In recognition of
this overarching flexibility and the need
to account for local conditions, Congress
directed EPA to allow states discretion
in how they determine the BART for
improving visibility. Id. Section
7491(b)(2)(A); Am. Corn Grower Ass’n v.
EPA, 291 F.3d 1, 8 (D.C. Cir. 2002)
(‘‘Congress intended the states to decide
which sources impair visibility and
what BART controls should apply to
those source.’’); see also 40 CFR
51.308(e)(1)(ii)(A).
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Against this backdrop of state
discretion, the CAA requires SIPs to
include: generally, ‘‘such emission
limits, schedules of compliance and
other measures as may be necessary to
make reasonable progress toward
meeting the national goal [of natural
visibility conditions in national parks
and wilderness areas],’’ 42 U.S.C.
7491(b)(2); ‘‘a long-term (ten to fifteen
years) strategy for making reasonable
progress toward meeting the national
goal,’’ id. Section 7491(b)(2)(B); and
more specifically, a plan for particular
sources to ‘‘procure, install, and operate,
as expeditiously as practicable (and
maintain thereafter) the best available
retrofit technology,’’ id. Section
7491(b)(2)(A).
Response: The CAA gives states
substantial but not unfettered discretion
in determining BART and reasonable
progress. We have already largely
addressed the assertions in this
comment in our responses to comments
on our legal authority. Furthermore, as
a hypothetical example, EPA would not
defer to a state determination that the
remaining useful life of a source is one
year if relevant evidence indicates the
remaining useful life is 20 years. Limits
on state discretion are inherent in the
CAA and our regulations; otherwise,
states would be free to reach decisions
that are arbitrary and capricious or
inconsistent with the purpose behind
the CAA and EPA’s regulations. As we
have stated, while we have approved
much of Wyoming’s SIP submittal, those
elements which we have disapproved
and for which we are finalizing a FIP
thwart the goals stated by Congress in
CAA section 169A and underlying the
RHR. Those statutory and regulatory
provisions cannot be simply dismissed
under the mantle of state discretion.
Comment: On May 28, 2009,
Wyoming published its BART
application analyses for the PacifiCorp
and Basin Electric facilities subject to
BART. Wyoming solicited public
comments on the analyses and to that
end held public hearings. EPA
commented on Wyoming’s analyses on
August 3, 2009. EPA was fully aware of
Wyoming’s BART proposals, but, at that
time EPA gave no indication that
Wyoming’s BART proposals violated the
CAA or were unreasonable.
Both PacifiCorp and Basin Electric
ultimately challenged Wyoming’s BART
determinations before the Wyoming
Environmental Quality Council. See
Appeal & Pet. for Review of BART
Permits, In re BART Permit Nos. MD–
6040 and MD–6042, No. 10–2801 (Wyo.
Envtl. Quality Council Feb. 26, 2010)
(PacifiCorp Petition); Appeal & Pet. for
Review, In re Basin Electric Power
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5075
Coop., No. 10–2802 (Wyo. Envtl.
Quality Council March 8, 2010) (Basin
Petition). The Environmental Quality
Council is an independent
administrative body charged with
adjudicating issues arising under
Wyoming environmental law, including
BART determinations. See Wyo. Stat.
Ann. Sections 35–11–111, 112.
Both Basin Electric and PacifiCorp
served their petitions for review on EPA
Region 8. EPA was again fully apprised
of Wyoming’s final BART decisions, as
well as the appeals of those decisions.
EPA elected not to participate in those
proceedings, and, again, provided no
indication that EPA viewed Wyoming’s
BART decisions as invalid.
After filing motions for summary
judgment, PacifiCorp and Basin Electric
both ultimately settled their litigation
with the State. The Environmental
Quality Council approved the
settlements after providing an
opportunity for public comment. EPA
did not comment on the settlement
agreements. Because no aggrieved
person appealed the Council’s decision
approving the settlements, the permit
decisions became final by operation of
law. Wyoming therefore incorporated
the BART permits into its SIP.
Years later, when EPA proposed
action on Wyoming’s SIP, EPA raised
for the first time its disagreement with
the BART decisions that PacifiCorp,
Basin, and Wyoming had already
litigated to conclusion. Because EPA
had the opportunity to participate in the
litigation and elected not to, EPA is now
precluded from collaterally attacking
those permit decisions. See, e.g., ADEC,
540 U.S. at 490 n.14. To conclude
otherwise—that EPA can forgo
participation in state adjudications only
to later attack the conclusions of those
state processes—is to give EPA the
power to nullify state court judgments.
Id. at 1015 (Kennedy, J., dissenting).
Congress did not intend to so empower
EPA to turn federalism on its head
through the regional haze program.
Response: EPA disagrees with this
comment. First, the comment does not
identify any way in which EPA is
precluded from exercising its authority
and duty under the CAA to ensure that
SIP submittals meet the requirements of
the Act. The notion that a state BART
determination is insulated from the
requirements of the Act merely because
the state has an administrative appeal
process is contrary to the Act itself as
well as the Supremacy Clause of the
U.S. Constitution. Had Congress wanted
to require EPA to participate in state
rulemaking or permit processes,
Congress would have explicitly stated
this in the Act. With respect to the
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ADEC dissent, it is just that, a dissent.
Even if the dissent were somehow
relevant, EPA is not nullifying a state
court judgment. The Wyoming
Environmental Quality Council is not
within the State judicial branch. It is an
executive agency. The members are
appointed by the Governor and serve at
the Governor’s pleasure. See Wyo. Stat.
Ann. Section 35–11–111(a) (‘‘Council
members shall be appointed by the
governor with the advice and consent of
the senate. The governor may remove
any council member as provided in
W.S. 9–1–202.’’); Section 9–1–202(a)
(‘‘[A]ny person may be removed by the
governor, at the governor’s pleasure, if
appointed by the governor to serve . . .
as a member of a state board or
commission.’’).
Furthermore, EPA’s comments to
Wyoming on its proposed SIP and
BART permits, which are in the docket
for this action, emphasized that we
would only come to a final conclusion
regarding the adequacy of Wyoming’s
BART determinations when we acted on
Wyoming’s regional haze SIP revision,
through public notice and comment
rulemaking. While we may have been
silent on some issues, silence from the
EPA does not signify implicit approval.
Any lack of participation by the EPA in
the state administrative appeal
proceeding or failure to register an
objection to the settlement agreement is
not an indication that a state’s proposed
BART determination will be approved
following its submittal as part of a larger
regional haze SIP, as discussed in
greater detail elsewhere in this
document. Wyoming is required to
adopt a final BART determination as
part of its regional haze SIP. As
explained elsewhere in this document,
once a state submits a SIP to the EPA,
we are authorized to approve, partially
approve, or disapprove the SIP, and we
have the duty to assure that the SIP
submittal complies with the
requirements of the Act. The statutory
scheme explicitly provides for this.
Alaska Depart of Environmental
Conservation v. Environmental
Protection Agency, 540 U.S. 461 (2004)
concerned EPA’s response to ADEC’s
issuance of a permit to a mine that
provided, as BACT, unreasonably low
NOX controls. Accordingly, EPA issued
three orders prohibiting ADEC from
granting the permit unless it
satisfactorily documented its reasoning
behind its BACT determination. The
Ninth Circuit held the three orders were
a proper exercise of EPA’s authority and
discretion. The Supreme Court affirmed.
EPA agrees with the commenter that
EPA made representations to the Court
stating the need to accord ‘‘appropriate
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deference’’ to states’ determinations.
EPA also agrees that we made the
representation that we have never
asserted our authority to override a
state-court judgment, and therefore, the
fear that EPA will threaten state courts’
independence is unfounded.
While EPA did make these
representations, these representations
are not inconsistent with EPA’s decision
to disapprove Wyoming’s BART
determination for Laramie River Station.
As explained above, we are not
overriding a state-court judgment.
Furthermore, the notion that a state
administrative appeal process can
insulate a BART determination from
federal requirements itself ‘‘turns
federalism on its head.’’ See U.S.
Constitution, Art. VI, cl. 2 (supremacy
clause).
In this instance, some of Wyoming’s
BART determinations were
unreasonable in terms of cost
effectiveness and other factors as
detailed elsewhere in this document
(detailed descriptions of the cost
assumption are described in the
comments specific to the units
elsewhere in this document).52 Finding
Wyoming’s BART determinations to be
unreasonable is a ‘‘restrained and
moderate’’ use of EPA’s statutory
authority. See 540 U.S. at n.14.
Following EPA’s issuance of orders to
ADEC for failing to establish a
reasonable BACT, the Court noted,
‘‘Only when a state agency’s BACT
determination is ‘not based on a
reasoned analysis’ . . . may EPA step in
to ensure that the statutory requirements
are honored.’’ 540 U.S. 461, 490. In the
case of Wyoming’s BART
determinations, EPA adhered to a
similar role. Upon finding some of
Wyoming’s BART determinations
unreasonable, EPA disapproved those
determinations and proposed an
alternative standard.
EPA continues to acknowledge the
importance of significant deference to
state authorities regarding their BART
determinations since they are in the best
position to make these determinations
given their close familiarity with the
unique characteristics of their particular
area. This structure encourages
cooperative federalism, a principle that
underlies the CAA. However, this
‘‘initial responsibility’’ does not permit
the state to make unreasonable BART
determinations. See 540 U.S. at 464.
EPA is not using its authority to
disapprove part of a state’s SIP as a way
52 As explained elsewhere in this document, EPA
has accepted some of the costs submitted in
response to the proposed notice developed for
Basin Electric, but not others.
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to override legitimate administrative
litigation reached under state law.
Rather, we are enforcing a requirement
of the CAA concerning anthropogenic
impairment of visibility by ensuring that
reasonable BART controls are
considered. State adjudicative processes
are not threatened because states are
free to use these processes to reach their
own BART determination, provided that
this determination is reasonable and
consistent with the CAA.
Comment: Nowhere does the Act
command national consistency in BART
cost estimates and, to the contrary, by
allowing states to make individualized
BART determinations, Congress
demonstrated that consistency was not
intended to be a component of the
regional haze program, save for the
uniform objective of attaining natural
visibility conditions. The commenter
indicated that the RHR takes the same
approach, allowing states wide
discretion to conduct BART analyses,
and that the BART Guidelines
encourage states to take into account
site-specific conditions that impact
costs. In light of these authorities, the
commenter believes that the EPA cannot
disapprove the State’s cost analyses
simply because they do not fit within
the EPA’s preferred vision of national
uniformity.
Another comment argued that EPA
claimed that the State failed to follow
the CCM, and the EPA supported this
claim by quoting the CCM as saying that
the EPA prefers consistency in control
cost estimates (78 FR 34749). The CAA,
the RHR, the BART Guidelines, and the
fact that different sources have vastly
different designs belie the EPA’s
preference for ‘‘consistency.’’ Nowhere
does the Act command national
consistency in BART cost estimates and,
to the contrary, by allowing states to
make individualized BART
determinations, Congress demonstrated
that consistency was not intended to be
a component of the regional haze
program, save for the uniform objective
of attaining natural visibility conditions.
The commenter indicated that the RHR
takes the same approach, allowing states
wide discretion to conduct BART
analyses, and that the BART Guidelines
encourage states to take into account
site-specific conditions that impact
costs. In light of these authorities, the
commenter believes that the EPA cannot
disapprove the State’s cost analyses
simply because they do not fit within
the EPA’s preferred vision of national
uniformity.
Response: As we explain in our
response to other comments in the legal
issue section, we have authority to
assess the reasonableness of a state’s
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analysis of costs; and a state’s discretion
must be reasonably exercised in
compliance with the applicable
requirements. While we agree that sitespecific challenges must be identified
and factored into the cost effectiveness
analysis, the SIP elements disapproved
elsewhere in this document items are
not ‘‘site-specific conditions,’’ but rather
use of the wrong costing methodology
and improper categorization of costs, as
well as other issues. An erroneous
analysis of costs, whether due to
methodological or to data flaws,
prevents a state from conducting a
meaningful consideration of the cost of
compliance factor. North Dakota v. U.S.
EPA, 730 F.3d 750, 761 (8th Cir. 2013).
EPA is not relegated to a ministerial
role. Id. We have not replaced cost
estimates, modeling analyses and other
SIP elements submitted by the State
solely for the purpose of ensuring
consistency across states. When a state
or source puts forward costs estimates
that are atypical, it is reasonable for us
to scrutinize such estimates more
closely to determine whether they are
reasonable or inflated. Also, given that
the assessment of costs is necessarily a
comparative analysis and one marker of
reasonableness, it is reasonable to insist
that certain standardized and accepted
costing practices be followed absent
unique circumstances. Such consistency
is particularly relevant for BART
determinations at fossil-fuel fired power
plants having a capacity in excess of 750
MW, which must be made pursuant to
the BART Guidelines.53 To the extent a
BART determination for such a power
plant is plainly inconsistent with EPAapproved determinations for similar
sources, it is more likely to be
inconsistent with the RHR and the
BART Guidelines and therefore to
warrant greater scrutiny for compliance
with the applicable requirements.
Comment: Basin Electric submits with
these comments an updated cost
estimate for SNCR and SCR emission
controls at Laramie River Station. That
report states that in Sergeant & Lundy’s
opinion SNCR would likely achieve a
48% reduction from EPA’s input
emission rate. However, when it made
its BART determination the State did
not have the benefit of this report and
made its judgment based on the best
information available at the time. EPA,
in its August 3, 2009 comments on
Wyoming’s BART permit for Laramie
River Station, stated that it estimated
that ‘‘SNCR can reduce NOX by 40%–
50% for most large boilers (EPA Air
Pollutions Control Cost Manual, 2002,
53 CAA section 169A(b) and 40 CFR
51.308(e)(1)(ii)(B).
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Sixth ed., EPA–452–02–001. Section
4.2, Chapter 1, pg. 1–3.).’’ States are
entitled to rely on information available
at the time they make BART
determinations, and EPA may not
disapprove a state’s BART based on
information that becomes available
later. This principle seems particularly
appropriate when at the time EPA itself
asserts the bona fides of information
similar to that relied upon by the State.
Response: We disagree with this
comment. EPA is required to take new
information submitted as part of this
rulemaking into consideration. Indeed,
EPA has taken into consideration the
updated cost estimate information
submitted by Basin Electric for SNCR
and SCR at Laramie River Station,
which was not available to Wyoming.
See Sierra Club v. EPA, 671 F.3d 955,
967 (9th Cir. 2012) (‘‘if new information
indicates to EPA that an existing SIP or
SIP awaiting approval is inaccurate or
not current, then, viewing air quality
and scope of emissions with public
interest in mind, EPA should properly
evaluate the new information and may
not simply ignore it without reasoned
explanation of its choice’’); see also 42
USC 7607(d)(6)(B) (‘‘The promulgated
rule shall also be accompanied by a
response to each of the significant
comments, criticisms, and new data
submitted . . . during the comment
period.’’) (emphasis added). Thus, EPA
is required, at a minimum, to take new
information into account during the SIP
approval process and, if necessary, alter
its final decision accordingly. As
explained in detail elsewhere, section
307(d) of the Act explicitly provides for
the consideration of information
developed after the proposed rule is
published.
EPA considered this new cost
information and the assessment of our
evaluation regarding this information
appears elsewhere in this document.
Comment: EPA is again overstepping
its role in this process. Wyoming
completed its BART analysis in 2009,
more than three years ago, and it would
have been impossible to incorporate the
alleged urea price increases in that
analysis. Simply put, Wyoming’s BART
determination is hardly arbitrary and
capricious simply because it failed to
take into account alleged urea price
increases some three years after
Wyoming completed its BART analysis.
Wyoming did precisely what the
Guidelines instruct: made a BART
determination based on information
available before the close of its public
comment period. 40 CFR Part 51, App.
Y., Section IV(D)(2)(3). To disapprove
Wyoming’s cost analysis based on
information that was not available to the
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5077
State would be to employ a ‘‘gotcha’’
approach that runs contrary to EPA’s
own regulations and counter to EPA’s
commitment to do its job fairly and
objectively. If the urea issue is truly
material, EPA should, at a minimum,
allow Wyoming to consider whether
this new information would affect its
BART determination before
disapproving that determination.
Another commenter suggests that urea
prices are relevant to operating costs for
SNCR but are not relevant to SCR. If the
State’s urea prices were too low, that
would mean the State had
underestimated the cost of SNCR, which
is what EPA claims in its proposal. 78
FR 34748. Such an underestimate would
have no material impact on the State’s
BART determination and thus provides
no basis for EPA’s disapproval. Once
again, this is a fact that in retrospect
supports the State’s BART decision,
rather than demonstrating it to be
arbitrary. If Wyoming’s estimate of the
cost of SNCR should have been higher,
as EPA maintains, the higher cost would
tend to add further support for rejecting
SNCR—the more expensive a control
technology, the stronger the reason to
reject it as BART. So if EPA is correct
in claiming the State’s assumed urea
price was too low, it is incorrect in
claiming this made a difference in the
State’s BART determination. A mistake
in a cost assumption, if there was a
mistake, is not a per se reason to reject
a BART determination. Such a mistake
would help support disapproval of a
cost analysis and resulting BART
determination only if it overstated costs
in a material way and thus tended to
make a technology appear significantly
more costly than it actually would be.
Response: We disagree with portions
of these comments. As we explained in
responses to similar comments below in
the section on Overarching Comments
on BART, we agree that a change in the
market price of urea, in and of itself,
may have not provided EPA sufficient
grounds for rejecting the State’s SNCR
analysis. However, we identified a
number of deficiencies in our proposed
rule, that when taken collectively, led
EPA to conclude that Wyoming’s
consideration of the costs of compliance
and visibility improvement for the EGUs
was inadequate and did not properly
follow the requirements in the BART
Guidelines and statutory requirements.
78 FR 34748. Therefore, regardless of
the market price of urea, EPA would
have reached the same conclusion.
Additionally, EPA is required to take
into account the urea price information
and we have taken that technical
information into account as detailed
elsewhere in this final notice and the
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docket. As explained in detail above,
while this information was not available
to the State, EPA nonetheless had a duty
to consider any new information
submitted during public comment when
reviewing the states’ SIPs. See Sierra
Club v. EPA, 671 F.3d 955, 967 (9th Cir.
2012).
Therefore, while the new urea cost
information was not available to the
State, EPA was nonetheless obligated to
consider any new information
submitted during public comment when
reviewing the states’ SIPs. Thus, EPA is
required, at a minimum, to take new
information into account during the SIP
approval process and, if necessary, alter
its final decision accordingly. Regarding
the comment that Wyoming should get
an opportunity to consider this
information before EPA takes final
action, see responses to similar
comments above.
Comment: EPA relies on its
consultant’s report as a basis for
rejecting Wyoming’s cost analysis for
SNCR and proposing to disapprove the
State’s NOX BART for Laramie River
Station. 78 FR 34748. EPA may not
reject the State’s estimate of the NOX
reduction achievable with SNCR just
because EPA’s consultant disagrees with
the State. Under the appropriate legal
standard, EPA must defer to the State’s
technical assessment absent
demonstration it is arbitrary and
capricious—which EPA has not
attempted to prove. Nor can EPA mount
a credible argument that its consultant’s
report is superior to the State’s. The
report does not comply with EPA’s own
Guidelines, as interpreted by EPA, and
ignores site-specific conditions that
have a huge impact on the cost of NOX
emission controls. Given the flaws in
the report, EPA’s reliance on it is not
only arbitrary and capricious, but
downright astonishing.
Response: We disagree with the
commenter’s assertion that we have
rejected the State’s estimate of cost
analysis for SNCR and the NOX
reduction achievable with SNCR just
because we disagree with the State.
During the public comment period on
our proposed rulemaking, Basin
Electric, as well as other parties,
submitted information concerning cost
estimates. We have placed this
information to the docket and as
explained elsewhere in this document,
taken it into account as part of this final
rulemaking. This final action clearly
explains the basis for our disapproval of
State’s NOX BART for Laramie River
Station, based on comments received
and our cost and visibility analysis, we
are disapproving others. We also
disagree that we are required to defer to
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the State’s technical judgments and to
apply an arbitrary and capricious
standard in reviewing the State’s SIP
submittal. We respond in detail to those
arguments elsewhere.
Comment: This commenter stated that
even if the Wyoming’s cost analyses
were revised to reflect the EPA’s high
urea prices, the average cost
effectiveness of SNCR would still be
consistent with the State’s original
analyses. The commenter noted that the
EPA’s average and incremental cost
effectiveness numbers for SNCR fall
well below the values considered by the
State to be cost effective and therefore
are consistent with the State’s original
conclusion that the costs of compliance
from the application of SNCR to the
EGUs were reasonable. The commenter
added that even if the State-analyzed
urea costs are adjusted to reflect EPA’s
urea costs, the average cost effectiveness
values remain below $2,600 dollars per
ton of NOX reduced and with
incremental cost effectiveness values
below $5,000 dollars per ton of NOX
reduced (citing commenter’s Exhibit
10), and those values are consistent with
the State’s original conclusion. The
commenter believes that it is clear that
the EPA does not take issue with
Wyoming’s cost analyses, but rather
Wyoming’s BART conclusions. The
commenter contended that the EPA’s
allegation that Wyoming incorrectly
analyzed costs is simply an excuse for
EPA to override Wyoming’s BART
determinations because EPA does not
like the result. The commenter asserted
that the EPA must explain why
Wyoming’s ultimate BART
determinations run afoul of the law,
rather than hold up allegations of
technical deficiencies as window
dressing for EPA to take over the role
Congress gave to states to make BART
determinations.
Response: We disagree with this
comment. As we explained earlier in
this final notice, Congress crafted the
CAA to provide for states to take the
lead in developing implementation
plans, but balanced that decision by
requiring EPA to review the plans to
determine whether a SIP meets the
requirements of the CAA. EPA’s review
of SIPs is not limited to a ministerial
type of automatic approval of a state’s
decisions. EPA must consider not only
whether the State considered the
appropriate factors but acted reasonably
in doing so. EPA has the authority to
issue a FIP either when EPA has made
a finding that the State has failed to
timely submit a SIP or where EPA has
found a SIP deficient. Here, EPA has
authority on both grounds, and we have
chosen to approve as much of the
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Wyoming SIP as possible and to adopt
a FIP only to fill the remaining gap. Our
action today is consistent with the
statute. We disagree that technical
deficiencies are mere ‘‘window
dressing’’; instead, appropriate technical
analyses are fundamental to a reasoned
BART determination. Finally, details of
technical issues regarding urea costs are
addressed elsewhere in this rule.
Comment: No single factor justifies
disapproval of the State’s BART. The
authority to determine BART belongs to
states, and BART determinations must
be based on all five BART factors
weighted together. States are
responsible for balancing those factors
and deciding how much weight to give
to each factor. 70 FR 39123, 39130,
39170. To show that Wyoming had been
arbitrary and capricious in making a
BART determination, EPA would bear a
heavy burden—a burden that it does not
even begin to meet based on a
disagreement that the State’s cost
analysis for SCR was in error. EPA’s
own incremental cost effectiveness for
SCR is more than $5000/ton, which is
a high cost even if lower than the
State’s. EPA makes no attempt to argue
that the difference between its
incremental cost effectiveness and the
State’s would have changed the State’s
selection of BART or rendered the
State’s BART arbitrary or illegal.
Response: We responded to similar
comments elsewhere. First, as we
explain in detail elsewhere, we disagree
that EPA’s review of a state’s SIP
submittal is limited to an arbitrary and
capricious standard. Second, as we
explain in detail elsewhere, we disagree
that states have the sole authority to
determine BART. Third, as we explain
in detail elsewhere, we disagree that a
‘‘harmless error’’ standard should be
applied.
Comment: In June of 2012, EPA
issued a proposal that analyzed the cost
effectiveness of various NOX control
technologies at Laramie River Station.
77 FR 33051. Although EPA disagreed
with the State’s NOX BART
determination for Laramie River Station,
EPA accepted and relied on the State’s
cost analysis for NOX controls, which
concluded that SCR would cost $3305
per ton of NOX removed, while SNCR
would cost $2036 per ton of NOX
removed. 77 FR 33051, Table 30 (These
values are for Unit 3. The State’s
conclusions for Units 1 and 2 were
similar.) In light of these estimates, EPA
eliminated SCR from consideration at
Laramie River Station ‘‘because the cost
effectiveness value is significantly
higher than LNBs with OFA and there
is a comparatively small incremental
visibility improvement over LNBs with
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OFA.’’ Id. EPA now expressly disavows
its earlier finding, apparently as a result
of comments that raised questions with
the State’s analysis and a cost analysis
prepared by Andover. 78 FR 34740,
34748. Yet EPA’s own cost analysis—
based entirely on the findings of a
technically infirm and legally
indefensible contractor analysis of the
costs of SNCR and SCR at Laramie River
Station—concludes that the cost
effectiveness of SCR at Laramie River
Station ranges from $3,589 to $3,903,
which exceed Wyoming’s cost
effectiveness demonstrations. Id. at
34774–34775. For EPA to take the
position SCR is now cost effective,
based on a higher estimate of tons NOX
removed that is inconsistent with its
earlier position and without any further
explanation, is arbitrary and capricious.
Cf. W. States Petroleum, 87F.3d at 284
(EPA ‘‘may not depart, sub silentio,
from its usual rules of decision to reach
a different, unexplained result in a
single case’’).
Response: We disagree with this
comment. EPA’s June 2012 Federal
Register notice was a ‘‘proposal,’’ not a
final agency action. Based on additional
information and analyses, on June 10,
2013 we reproposed to partially approve
and partially disapprove the Wyoming
SIP. Therefore, contrary to commenter’s
assertions, we had not taken a final
agency action in June 2012 and the
Western States Petroleum case in not
applicable here. In addition, we fully
explained the reasons for the changes in
our proposed action. We note that
adjustments in cost-effectiveness of SCR
were not the only factor in our proposed
changes. We also revised modeling of
visibility benefits of SNCR and SCR and
cost-effectiveness of SNCR, which
played a role in our reproposed BART
determination.
2. Compliance With Section 307(d)
Comment: EPA cannot adopt a FIP
using a procedure that simultaneously
proposes both disapproval of a SIP
BART determination and a different
BART determination as a FIP. Doing so
results in a violation of Section 307(d),
which requires EPA to first announce
the ‘‘statement of basis and purpose’’
that accompanies the FIP, including a
summary of ‘‘the factual data on which
the . . . rule is based’’ and ‘‘the major
legal interpretations and policy
considerations underlying the . . .
rule.’’ 42 U.S.C. 7607(d)(1)(B), (d)(3)(A)
& (C), (d)(6)(A). The reason is simple.
BART determinations are inherently
technical evaluations that consider
costs, feasibility, potential plant shutdowns, etc. The same requirement
would apply to any BART
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determination undertaken by EPA as
part of a FIP. Thus, any response by
EPA to comments that Basin Electric
and others submit in support of
Wyoming’s BART determination will
necessarily have to deal with new
detailed technical information and data,
particularly when, as here, EPA has
initially proposed to reject a BART
determination as inadequately
supported and thus has invited
extensive comments. EPA’s responses to
comments will then necessarily become
part of the grounds supporting any new
BART determination in a FIP, but will
not have been publicly disclosed until
EPA’s response to comments on the SIP.
Thus, EPA will be unable to provide a
substantive statement of basis and
purpose for the FIP in the same proposal
to disapprove the SIP unless it intends
to ignore comments. Yet this violates
EPA’s statutory obligation to announce
all the facts and grounds supporting a
FIP before adoption. It also wholly
undermines the underlying purposes of
the APA’s notice and comment
obligations. See, e.g., United States v.
Cain, 583 F.3d 408, 420 (6th Cir. 2009)
(these obligations are intended to
‘‘ensure fair treatment for persons to be
affected by regulation’’ and to ‘‘ensure
that affected parties may participate in
decision making at an early stage’’’)
(citations omitted); NRDC v. Thomas,
805 F.2d 410, 437 (D.C. Cir. 1986) (the
purposes of these obligations include
that ‘‘notice improves the quality of
agency rulemaking by ensuring that
agency regulations will be tested by
exposure to diverse public comment,’’
that ‘‘notice and the opportunity to be
heard are an essential component of
fairness to affected parties,’’ and that
‘‘by giving affected parties an
opportunity to develop evidence in the
record to support their objections to a
rule, notice enhances the quality of
judicial review’’) (quoting Small Refiner
Lead Phase-Down Task Force v. EPA,
705 F.2d 506, 547 (D.C. Cir. 1983).
This must be true, unless EPA’s
proposed course of action has already
been determined, meaning that EPA has
already decided to reject the SIP BART
determinations and replace them with
its own regardless of the comments
submitted. Such prejudgment would be
contrary to law. See, e.g., Davis v.
Mineta, 302 F.3d 1104, 1112 (10th Cir.
2002) (plaintiffs were likely to prevail in
showing agency acted arbitrarily and
capriciously, in part because the agency
‘‘prejudged the NEPA issues’’); Metcalf
v. Daley, 214 F.3d 1135, 1146 (9th Cir.
2000) (agencies’ environmental
assessment prepared under NEPA was
‘‘demonstrably suspect’’ and ‘‘fatally
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5079
defective’’ because the agencies ‘‘were
predisposed’’ to a particular finding;
agencies must conduct ‘‘an objective
evaluation free of the previous taint’’).
Yet that is plainly what EPA is
suggesting by its effort to
simultaneously disapprove one BART
determination while proposing another.
Either EPA must ignore the comments
so as not to establish new grounds for
the FIP, or it must reject the comments
on substantive grounds that become
justification for the FIP but have never
been publicly disclosed. Either way, its
action violates APA standards.
This is a consequence of the
procedural posture into which EPA has
put itself by taking no action on the SIP
until the end of the Sections 110(c) FIP
clock. To follow the requirements of
Sections 307(d), EPA must first propose
to disapprove a SIP, take comment, and
then make a decision after full and fair
consideration of the comments. If, after
open-minded consideration of the
comments, EPA continues to believe the
SIP must be disapproved, then and only
then can EPA lawfully propose a
different BART determination in a FIP,
articulating for public comment why the
proposed federal BART determination is
legal and the State BART determination
is not.
Failure to follow this procedure
necessarily results in a violation of the
law, one way or another. Nor does the
existence of a Consent Decree excuse
EPA’s failure to follow the correct
procedure. A court-fashioned decree
may not foreclose the total range of
procedural options available to an
agency. See Watt v. Energy Action Educ.
Found., 454 U.S. 151, 168–69 (1981)
(refusing to limit the procedural options
within the discretion of an agency);
Marina T. Larson, Consent Decrees and
the EPA: Are They Really Enforceable
Against the Agency?, 1 Pace Envt’l L.
Rev. 147, 160–63 (1983) (arguing that
consent decrees may not limit agency
procedural options). EPA waited until
compelled by Court Order to propose
disapproval of the State BART
determination, but could have done so
much earlier. In any event, the
obligations EPA negotiated for itself in
the Consent Decree cannot be used to
deprive Wyoming or Basin Electric the
substantive procedural rights afforded
by the CAA.
Response: EPA disagrees with this
comment, which fundamentally
misunderstands the nature of noticeand-comment rulemaking. As the Ninth
Circuit stated in another context:
Nothing prohibits the Agency from adding
supporting documentation for a final rule in
response to public comments. In fact,
adherence to the [petitioners’] view might
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result in the EPA’s never being able to issue
a final rule capable of standing up to review:
every time the Agency responded to public
comments, such as those in this rulemaking,
it would trigger a new comment period.
Thus, either the comment period would
continue in a never-ending circle, or, if the
EPA chose not to respond to the last set of
public comments, any final rule could be
struck down for lack of support in the record.
Rybachek v. U.S. EPA, 904 F.2d 1276,
1286 (9th Cir. 1990).
In the context of the CAA, the specific
rulemaking provisions in section 307(d)
are in accord with this. Under section
307(d)(3), the notice for the proposed
rule must be accompanied by a
statement of basis and purpose,
including ‘‘a summary of (A) the factual
data on which the proposed rule is
based; (B) the methodology used in
obtaining the data and in analyzing the
data; and (C) the major legal
interpretations and policy
considerations underlying the proposed
rule.’’ 42 USC 7607(d)(3) (emphasis
added). ‘‘All data, information, and
documents referred to in [section
307(d)(3)] on which the proposed rule
relies shall be included in the docket on
the date of publication of the proposed
rule.’’ Id. (emphasis added). Then,
under section 307(d)(6), the
promulgated rule must ‘‘be
accompanied by (i) a statement of basis
and purpose like that referred to in
[section 307(d)(3)] with respect to a
proposed rule.’’ 42 USC 7607(d)(6)(A)
(emphasis added). In other words, the
statement of basis and purpose must
provide a summary of (among other
things) the factual data and
methodologies on which the
promulgated rule is based. In addition,
section 307(d)(6) specifically requires a
‘‘response to each of the significant
comments, criticisms, and new data
submitted . . . during the comment
period.’’ 42 USC 7607(d)(6)(B)
(emphasis added). And finally, ‘‘the
promulgated rule may not be based . . .
on any information or data which has
not been placed in the docket as of the
date of such promulgation,’’ id.
7607(d)(C), which by implication allows
EPA to base the promulgated rule on
information and data that is placed in
the docket before the date of
promulgation. Thus, section 307(d)(6)
specifically contemplates that the
Agency can in its promulgated rule rely
on additional information and data that
EPA develops after the proposed rule
has been published.
In this instance, our FIP proposal was
in accord with the requirements of
section 307(d) of the Act. In particular,
before the proposed rule was published,
we included in the docket all the factual
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data, such as cost estimates and
visibility modeling, on which the
proposed rule was based. The comment
identifies no deficiency in this regard.
Instead, according to the comment the
supposed deficiency is the failure to
include in the docket for the proposal
the data and information that EPA will
develop to respond to comments. But, as
discussed above, this is no deficiency;
instead section 307(d) specifically
contemplates that this will happen.
The argument in the comment
regarding EPA’s alleged prejudgment of
its decision also belies a
misunderstanding of notice-andcomment rulemaking. Under the
comment’s theory, in order to not have
‘‘prejudged’’ the outcome, EPA would
have to avoid proposing any particular
outcome in its notice of proposed
rulemaking. However, under section
307(d)(3), ‘‘the notice of proposed
rulemaking shall be published in the
Federal Register, as provided under
section 553(b) [of the APA].’’ Under
section 553(b) of the APA, the ‘‘notice
shall include’’ (among other things)
‘‘either the terms or substance of the
proposed rule or a description of the
subjects and issues involved.’’ 5 USC
553(b)(3) (emphasis added). Thus it is of
course explicitly permitted under the
CAA and the APA for a proposal notice
to contain EPA’s proposed disapproval
of the State’s BART determinations and
EPA’s proposed FIP BART
determinations. This does not indicate
prejudgment at all; indeed in this action
EPA is adjusting certain determinations
in response to certain comments, and in
fact EPA previously reproposed its
action on Wyoming’s SIP based upon
new information submitted by the
public (77 FR 3302). The cases cited by
the comment regarding prejudgment
concern NEPA analysis and are not on
point.
As the commenter noted, regional
haze requirements apply both to our
action on Wyoming’s SIP submittal and
our FIP. EPA disagrees that the BART
determinations in its FIP, which must
meet the same regional haze
requirements as the BART
determinations in Wyoming’s SIP, must
be published in a separate rulemaking
procedure. To the extent that a comment
on our proposed disapproval was
identified as also relevant to our
proposed FIP, we have responded to it.
The commenter was not deprived of
procedural rights merely because the
commenter could not submit
information twice in two separate
rulemakings. All affected parties had
ample opportunity to submit any
pertinent information to EPA.
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Regarding the consent decree, we
have elsewhere explained that it did not
limit or modify EPA’s substantive
discretion. With respect to the
comment’s argument that it improperly
limited EPA’s procedural discretion,
any such limits are found in the
statutory deadlines and mandatory
duties in the Act itself. The case cited
in the comment, Watt v. Energy Action
Educ. Found., 454 U.S. 151 (1981), did
not concern a consent decree and is not
on point. In it, the Supreme Court was
‘‘unable to find anything, either in the
legislative history or in the 1978
Amendments [to the Outer Continental
Shelf Lands Act] themselves, that
compels the conclusion that the
Congress as a whole intended to limit
the Secretary of the Interior’s
discretion’’ with respect to choice of
bidding systems for oil and gas leases.
Id. at 168. By contrast, the CAA sets
certain statutory deadlines for EPA’s
action on SIP submittals and FIP
promulgations and thereby explicitly
limits the Administrator’s discretion for
final action. We elsewhere respond to
comments that EPA’s promulgation of
its FIP was outside EPA’s authority
under 110(c) of the Act. Finally, the
cited law review article, Marina T.
Larson, Consent Decrees and the EPA:
Are They Really Enforceable Against the
Agency?, 1 Pace Envt’l L. Rev. 147
(1983), is also not on point. It discusses
a settlement agreement which ‘‘set[ ]
forth specific methods and formalized
criteria for the [A]dministrator to use in
assessing the need for regulation. These
rules [would] control the nature of the
data collected and its subsequent
interpretation, and [would] have a
significant influence on the substantive
decisions reached.’’ Id. at 162. No such
constraints have been placed on our
methods and use of data in the
aforementioned consent decree. We
respond elsewhere to comments about
procedural due process rights.
3. Compliance With Section 169A(d)
Comment: One commenter argued
that section 169A(d) of the CAA
requires that before holding a hearing on
a proposed regional haze plan, ‘‘the
State (or the Administrator, in the case
of a [FIP]), shall consult in person with
the appropriate federal land manager
(FLM) or managers and shall include a
summary of the conclusions and
recommendations of the FLMs in the
notice to the public.’’ 42 U.S.C. 7491(d).
In its proposed action, EPA recites this
land manager consultation requirement
as it applies to SIPs, 78 FR 34744, but,
EPA notably ignores that this
requirement applies equally to FIPs.
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The commenter asserted that not once
in any of EPA’s public notices of the
hearings EPA held on its proposed FIP
did EPA include a summary of the
conclusions and recommendations of
the FLMs in the notice to the public. See
78 FR 34738 (June 10, 2013); 78 FR
40654 (July 8, 2013). Consequently, the
commenter argued that EPA cannot rely
on the State’s public notices because the
State held its public hearings years
before EPA proposed its FIP and
because the SIP differs substantially
from the FIP.
The commenter argued that EPA’s
failure to comply with Section 169A(d)
can be understood only as arbitrary and
capricious. The CAA has required
consultation with FLMs, which oversee
the Class I areas the regional haze
program aims to protect, from the very
beginning of the regional haze program,
see 42 U.S.C. 749l(a)(2), and
continuously through the development
of each implementation plan, id.
Sections 749l(d). Congress therefore
understood the importance of working
closely with FLMs in regional haze
planning.
In 1999, EPA plainly understood the
significance of consulting the FLMs
when it promulgated the RHR. See 64
FR 35714, 35747 (July 1, 1999)
(describing land manager consultation
as ‘‘important and necessary’’). Both
times EPA proposed action on
Wyoming’s SIP—in 2012 and again in
2013—EPA reiterated the need to
consult with FLMs when developing a
regional haze implementation plan. 77
FR 33022, 33028 (June 4, 2012); 78 FR
34738, 34744–45 (June 10, 2013).
Against this backdrop, the commenter
explained, EPA’s failure to explain why
EPA believed it did not have to consult
with the FLMs when promulgating its
FIP for Wyoming, let alone comply with
the simple consultation process set forth
in Section 169A(d), is plainly arbitrary
and capricious. Because FLMs play a
critical statutory role in the regional
haze program, there is a substantial
likelihood that EPA’s proposed FIP
would be significantly different if EPA
had complied with Section 169A(d).
Response: EPA agrees that
consultation with the FLMs is an
important aspect of the regional haze
program. EPA has engaged with the
appropriate FLMs on all of its regional
haze actions, including its proposed
actions on the Wyoming regional haze
SIP. While EPA did not include a
summary of the FLMs’ conclusions and
recommendations on the proposed FIP
in the public hearing notices, those
conclusions and recommendations are
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readily available to the public in the
online docket for this rulemaking.54
EPA also disagrees with the
commenter that the consultation
materials contained in the State’s public
notices are irrelevant just because the
State conducted its public hearings
many years ago. The FLMs concluded at
that time that the Wyoming regional
haze SIP did not adequately protect the
State’s Class I areas, and these
conclusions and recommendations
informed EPA when we proposed to
disapprove portions of the Wyoming
regional haze SIP and issue a FIP.
Finally, there is no basis to the
commenter’s claim that EPA’s proposed
FIP would be significantly different if
we had included the FLMs’ conclusions
and recommendations in the public
hearing notices. We carefully
considered the comments of the FLMs
and have responded to them elsewhere
throughout this document. As those
responses explain in more detail, we
have chosen not to change our proposed
NOX BART determinations in all of the
ways in which the FLMs requested. We
point out, however, that had EPA
adopted the FLMs’ recommendations,
we would be requiring SCR on all of the
BART-eligible EGUs in Wyoming, a
result that this particular commenter
has vigorously opposed.
Comment: The processes Congress
required EPA to follow under the
regional haze program were
circumvented. For example, the CAA
requires both states and EPA to consult
with FLMs on regional haze
implementation plans. Public notice of
the FLMs’ conclusions and
recommendations is to occur before
holding a hearing on the plan. While
EPA recites this requirement in its
proposed action, it utterly failed to
include any FLM consultation on behalf
of its agency. EPA held three hearings
and not once in any hearing did the EPA
indicate it had consulted the FLMs in
Wyoming and no conclusions or
recommendations of any consultations
were provided.
Response: See above response.
4. Public Hearings
Comment: EPA’s regional haze plan
promulgation regulations require EPA to
provide public notice at least thirty days
in advance of a hearing on a proposed
implementation plan. 40 CFR 51.102(d)
(a plan hearing ‘‘will be held only after
reasonable notice, which will be
considered to include, at least 30 days
prior to the hearing(s)’’); see also 40 CFR
51.100(i). Although EPA held three
54 EPA–R08–OAR–2012–0026–0134, and EPA–
R08–OAR–2012–0026–0068.
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public hearings on its proposed FIP for
Wyoming, not once did EPA provide the
public at least thirty days advance
notice of the hearing. EPA proposed its
FIP on June 10, 2013 and provided only
fourteen days notice of its hearing on
the proposal. 78 FR 34738, 34738. After
Governor Mead, Wyoming’s
Congressional Delegation, and the
Wyoming Department of Environmental
Quality (DEQ) pointed out to EPA that
fourteen days provided far too
inadequate notice for the public to
understand the proposed FIP and
therefore meaningfully participate in the
public hearing, EPA agreed to hold two
additional hearings. On July 8, 2013,
EPA publicly noticed its plans to hold
the additional hearings on July 17, 2013
and July 26, 2013. 78 FR 40654, 40654.
Thus, although EPA had the
opportunity to correct its errors, it failed
to do so by again providing less than
thirty days notice of its hearings.
Here again, EPA’s noncompliance
with its own regulatory processes is
arbitrary and capricious. EPA cannot
ignore the law for its own benefit
without at least providing a reasoned
justification for doing so. In this case
EPA has provided no such explanation,
thereby rendering its failure an arbitrary
abuse of power. And by shortcutting
public participation, EPA undermined
the central democratic purposes of
notice-and-comment rule-making. Had
EPA honored the law and held itself to
the same standards it holds states, the
public could have more meaningfully
commented on EPA’s proposal. As a
result of that public input, EPA’s
proposed FIP might be considerably
different, assuming, as we must, that
EPA would have considered those
comments with an open mind.
DEQ understands that EPA rushed its
FIP promulgation process in order to
meet the deadlines it consensually
established with a third party in
litigation to which Wyoming was not a
party. But, EPA’s outside arrangements
do not excuse it from complying with
the law, or allow it to shortcut public
participation in the promulgation of a
rule, especially one that will harm
Wyoming. DEQ discourages EPA from
imposing its illegally promulgated FIP
on Wyoming. But, in the event EPA
decides nevertheless to do so, DEQ
encourages EPA to re-propose its FIP in
a manner that complies with the
statutory and regulatory plan
development processes. To do otherwise
is to arbitrarily hold states to a different
plan promulgation standard than EPA
itself adheres to, even though the CAA
makes no such distinction. Such
irrationally unequal treatment is the
essence of arbitrary regulation.
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Response: EPA disagrees with this
comment. First, 40 CFR 51.102(d)
implements the requirement in section
110(a)(2) that state plans ‘‘be adopted by
the State after reasonable notice and
hearing.’’ See 72 FR 38787 (July 16,
2007). When EPA—which is not a
state—promulgates a FIP, EPA instead is
bound by the requirements in section
307(d) of the Act. EPA has not
promulgated specific regulations
governing EPA’s processes under
section 307(d); however, EPA complied
with the public hearing requirements in
307(d) as explained below. The
definition of ‘‘State agency’’ in 51.100(i)
does not contradict this; indeed the
commenter elsewhere protests
vigorously elsewhere that states, not
EPA, are ‘‘primarily responsible for
development and implementation of a
plan under the Act.’’ 40 CFR 51.100(i).
Thus, EPA does not fall under the
definition of ‘‘State agency.’’ We also
note that EPA initially provided a 60day comment period for this action and
then extended it 15 more days; under 40
CFR 51.102. States need only provide a
30-day period for written comments.
See 72 FR at 38788 (‘‘Whether or not a
public hearing is held, the State is
required to provide a 30-day period for
the written submission of comments
from the public.’’).
In promulgating a FIP under CAA
section 110(c), EPA is required to: ‘‘give
interested persons an opportunity for
the oral presentation of data, views, or
arguments, in addition to an
opportunity to make written
submissions; keep a transcript of any
oral presentation; and keep the record of
such proceeding open for thirty days
after completion of the proceeding to
provide an opportunity for submission
of rebuttal and supplementary
information.’’ 55 In this rulemaking, EPA
held three public hearings on its
proposed FIP. In addition to the public
hearing initially scheduled on June 24,
2013 in Cheyenne, Wyoming, additional
public hearings were held on July 17,
2013 in Cheyenne, Wyoming and on
July 26, 2013 in Casper, Wyoming. The
transcripts for those hearings consisted
of 321 pages. These hearings were
announced in the Federal Register on
June 10, 2013 and July 8, 2013,56 and a
pre-publication version of the proposal
was posted on EPA’s Web site prior to
publication in the Federal Register. The
proposal was published in the Federal
Register on June 10, 2013 and was
initially scheduled to close on August 9,
2013. The public comment period was
extended in response to letters received
55 See
56 78
CAA section 307(d).
FR 34738, and 78 FR 40654.
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from the Governor and Congressional
delegation, which are in the docket for
this action, and public comments were
accepted through August 26, 2013, 30
days after the last hearing, as required.
EPA received over 1900 comments on
the reproposal, including over 130
unique comments submitted from
organizations, companies, and
individuals. The major comments
consisted of over 1130 pages, including
attachments. The commenters have not
explained how their ability to comment
was impaired in any way by the
opportunities for public comment that
EPA provided, including three public
hearings and the 75-day comment
period.
Comment: EPA failed to follow its
own rules for providing public notice of
hearings on regional haze
implementation plans. Those rules
require a minimum of 30 days advance
public notice of hearings on
implementation plans. The first notice
in the Federal Register of a public
hearing was issued on June 10, 2013, for
a public hearing to be held on June 24,
2013. EPA issued a second notice for
additional public hearings on July 8,
2013 in the Federal Register. The notice
identified July 17, 2013 and July 26,
2013 as dates set. This provided the
public nine and eighteen days notice of
the respective hearings.
Response: We disagree with this
comment, see above response.
5. RHR and BART Guidelines
Comment: Regardless of the effect of
AFUDC on cost effectiveness as
demonstrated by the Sargent & Lundy
sensitivity analyses, EPA has no
authority, as part of its interpretation of
a non-binding guidance document, to
impose restrictions on the categories of
costs that states can include when
assessing the ‘‘costs of compliance’’ in
a BART determination. EPA has failed
to make a showing that Wyoming’s
compliance with Sections 169A(g)(2) or
otherwise violates governing law.
Including AFUDC is not a lawful ground
for disapproving Laramie River Station
BART, and it is improper to exclude
AFUDC in EPA’s FIP analysis for
Laramie River.
Response: EPA disagrees with this
comment. EPA’s revised costeffectiveness values are consistent with
EPA’s regulations and the parameters
set forth in the Control Cost Manual.
EPA explained in promulgating the
BART Guidelines that ‘‘[s]tates have
flexibility in how they calculate costs.
‘‘See 70 FR at 39127 (July 6, 2005). A
state may deviate from the Control Cost
Manual provided its analysis is
reasonable. EPA independently
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evaluated Sargent & Lundy costeffectiveness calculation, explaining
elsewhere in this document that the
CCM explicitly excludes AFUDC from
control costs, and EPA’s estimates were
correct in excluding AFUDC. See
Oklahoma v. U.S. EPA, 723 F.3d 1201,
1212 (10th Cir. 2013) (‘‘The EPA
therefore had a reasonable basis for
rejecting the 2008 Cost Estimates [that
were based on the overnight costing
method] as not complying with the
guidelines.’’)
Furthermore, as Region 9 explained in
responding to similar comments: 57
EPA disagrees ‘‘with commenters’
assertions that AFUDC is a cost that should
be incorporated into our cost analysis, as it
is inconsistent with CCM methodology. The
utility industry uses a method known as
‘‘levelized costing’’ to conduct its internal
comparisons, which is different from the
methods specified by the CCM. Utilities use
‘‘levelized costing’’ to allow them to recover
project costs over a period of several years
and, as a result, realize a reasonable return
on their investment. The CCM uses an
approach sometimes referred to as overnight
costing, which treats the costs of a project as
if the project were completed ‘‘overnight’’,
with no construction period and no interest
accrual. Since assets under construction do
not provide service to current customers,
utilities cannot charge the interest and
allowed return on equity associated with
these assets to customers while under
construction. Under the ‘‘levelized costing’’
methodology, AFUDC capitalizes the interest
and return on equity that would accrue over
the construction period and adds them to the
rate base when construction is completed
and the assets are used. Although it is
included in capital costs, AFUDC primarily
represents a tool for utilities to capture their
cost of borrowing and return on equity
during construction periods. AFUDC is not
allowed as a capitalized cost associated with
a pollution control device under CCM’s
overnight costing methodology, and is
specifically disallowed for SCRs (i.e., set to
zero) in the CCM.58 Therefore, in reviewing
other BART determinations, EPA has
consistently excluded AFUDC.59
Comment: EPA claims that Wyoming
should have used actual emissions
during the baseline period instead of
calculating baseline emissions from the
actual average heat input and actual
average emission rate. EPA apparently
claims that this deviated from the BART
Guidelines. 78 FR 34773–34774.
57 77 FR 72512, 72531 (Dec. 5, 2012)(BART for
Apache, Cholla and Coronado).
58 CCM (Tables 1.4 and 2.5 show AFUDC value
as zero).
59 See, e.g., 77 FR 20894, 20916–17 (Apr. 6, 2012)
(explaining in support of the North Dakota Regional
Haze FIP, ‘‘we maintain that following the
overnight method ensures equitable BART
determinations . . .’’); 76 FR 52388, 52399–400
(August 22, 2011) (explaining in the New Mexico
Regional Haze FIP that the Manual does not allow
AFUDC).
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However, the Guidelines do not
mandate EPA’s approach. They say,
rather, that the baseline emissions rate
‘‘should represent a realistic depiction
of anticipated annual emissions for the
source’’ and ‘‘in general’’ states should
estimate anticipated emissions based on
actual baseline emissions. 70 FR 39167.
Nothing in the text of the Guidelines
requires states to use any particular
approach to estimate future emissions.
The Guidelines were constructed to
assist the states in making cost
assessments, not to mandate the same
assessment and the same results in
every case by use of mandatory
checklists. The word ‘‘should’’ in the
Guidelines makes clear there is no
mandatory action required. See Aragon
v. United States, 146 F.3d 819, 826
(10th Cir. 1998) (describing Air Force
Manual 85–14’s use of the word
‘‘should’’ as ‘‘suggestive, rather than
mandatory language’’ in a Federal Tort
Claims Act case); In re Glacier Bay, 71
F.3d 1447, 1452–53 (9th Cir. 1995)
(interpreting the National Oceanic and
Atmospheric Administration’s use of
the word ‘‘should’’ in manuals and
instructions as ‘‘suggestive’’ language
conferring hydrographers with
discretion); Culbert v. Young, 834 F.2d
624, 628 (7th Cir. 1987) (holding that
use of the word ‘‘should’’ in a
Wisconsin Administrative Code
provision governing inmate discipline
‘‘only advises the security director on
what criteria to consider but does not
require him to consider them,’’ and
explaining that ‘‘[t]he word ‘should,’
unlike the words ‘shall,’ ‘will,’ or ‘must,’
is permissive rather than mandatory’’).
See also Dickson v. Sec’y of Defense, 68
F.3d 1396, 1401 (D.C. Cir. 1995) (‘‘When
a statute uses a permissive term such as
‘may’ rather than a mandatory term such
as ‘shall,’ this choice of language
suggests that Congress intends to confer
some discretion on the agency, and that
courts should accordingly show
deference to the agency’s
determination.’’) (emphasis omitted).
EPA is therefore merely disagreeing
with a judgment call made by the State,
not pointing to violation of a mandatory
methodology. And, even though not
required to do so, Wyoming did follow
the recommendation in the Guidelines.
Although EPA contends that the State
used a baseline based on annual average
heat input for 2001–2003 and an
emission rate of 0.27 rather than the
‘‘actual annual average’’ emissions, 78
FR 34773–34774, the State’s May 28,
2009 BART Analysis actually says
‘‘[b]aseline emissions [are] based on
continuous emissions monitoring (CEM)
annual averages for 2001–2003.’’
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But even if EPA were correct, EPA
would still be wrong in asserting that
the State failed to follow the BART
Guidelines. The approach that EPA
objects to would be an appropriate
method to realistically depict
anticipated annual emissions. Certainly
it would be reasonable to multiply the
actual annual amount of heat in Laramie
River coal during the baseline period by
the same baseline emission rate of 0.27
lb/MMBtu that was used by EPA’s own
consultant. 78 FR at 34773; Review of
Estimated Compliance Costs for
Wyoming Electric Generating (EGUs)—
Revision of Previous Memo, memo from
Jim Staudt, Andover Technology
Partners, to Doug Grano, EC/R, Inc., Feb.
7, 2013 (‘‘Andover Report’’) at 15 Table
4, EPA docket cite EPA–R08–OAR–
2012–0026–0086. Any estimate of
anticipated emissions is necessarily a
projection, and by definition cannot
require exclusive reliance on past actual
emissions.
That the State’s approach to baseline
emissions was a realistic projection is
borne out by the fact that the annual
baseline emissions the State used to
calculate cost effectiveness for Laramie
River differs from EPA’s baseline by
only the following de minimis amounts:
269 tons higher than EPA’s 6051 tons
for Unit 1, a difference of only 4%; 8
tons lower than EPA’s 6285 tons for
Unit 2, a difference of only 0.1%; and
73 tons higher than EPA’s 6375 tons for
Unit 3, a difference of only 1%. No fair
assessment could conclude that such de
minimis differences violate the
Guidelines or yield an ‘‘implausible’’
result so extreme as to be arbitrary and
capricious. 78 FR 34773–34776.
If EPA’s values are realistic, the
State’s values are realistic. There is no
material difference between them. The
objective of a BART determination is to
arrive at a technology selection that
weighs and takes into account the five
BART factors. The negligible difference
between EPA’s baseline emissions and
the State’s is not material and therefore
is not a valid ground for disapproving
the State’s NOX BART for Laramie
River, and EPA has made no effort to
show otherwise. EPA’s role is not to fly
speck each and every aspect of the
BART process in a search for reasons to
disapprove the State’s determination.
In fact, EPA proposes to approve other
BART determinations made by
Wyoming despite the same alleged
‘‘errors,’’ unequivocally demonstrating
that its disagreement with Wyoming’s
approach to baseline calculations does
not amount to proof of a legal violation
by the State. EPA claims that for several
Wyoming sources subject to BART,
Wyoming committed the same ‘‘cost and
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visibility errors’’ that EPA claims for
Laramie River, but proposes nonetheless
to approve the BART determinations for
these sources ‘‘because we have
determined that the State’s conclusions
were reasonable despite the cost and
visibility errors.’’ 78 FR 34750. EPA
contradicts itself when it overlooks
errors for other sources and yet claims
those same ‘‘errors’’ as per se reasons to
disapprove BART for Laramie River
Station. Such inconsistent treatment is
erroneous. See W. States Petroleum v.
EPA, 87 F.3d 280, 282 (9th Cir. 1996).
EPA’s own behavior therefore
demonstrates that the baseline used for
Laramie River is not a material
departure from any requirement and is
not a basis for disapproval of the State’s
BART determination. EPA is stretching
to find any excuse to impose its own
technology preferences, contrary to law.
Wyoming’s choice of baseline
emissions is neither inconsistent with
the BART Guidelines nor materially
different from EPA’s allegedly correct
baseline emissions, and therefore is not
a valid ground for disapproving
Wyoming’s NOX BART for Laramie
River.
Response: We disagree with some
aspects of this comment, but agree with
others. First, we disagree with the
commenter’s characterization of the
BART Guidelines as other than
mandatory in the case of Laramie River
Station, including in regard to how
baseline emissions are calculated. The
generating capacity of Laramie River
Station of 1,705 MW surpasses the
threshold of 750 MW used to determine
whether the BART Guidelines must be
applied. As stated in the RHR: ‘‘The
determination of BART for fossil-fuel
fired power plants having a total
generating capacity greater than 750
megawatts must be made pursuant to
the guidelines in appendix Y of this part
(Guidelines for BART Determinations
Under the Regional Haze Rule).’’ 60
Moreover, the commenter’s attempts to
turn ‘‘should’’ into ‘‘may’’ are of no
avail. Because the BART Guidelines are
mandatory for EGUs larger than 750
MW, EPA’s use of the word ‘‘should’’
indicates a mandate, not a suggestion.
Elsewhere in the Guidelines, EPA uses
‘‘may’’ when EPA means ‘‘may.’’ See,
e.g. 40 CFR Part 51, App’x Y, II.A.4 (‘‘In
order to simplify BART determinations,
States may choose to identify de
minimis levels of pollutants at BARTeligible sources (but are not required to
do so).’’) (emphasis added).
Furthermore, the Tenth Circuit Court of
Appeals has interpreted ‘‘should’’ in the
Guidelines to mean ‘‘required.’’ See
60 40
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Oklahoma v. U.S. EPA, 723 F.3d 1201,
1213 (10th Cir. 2013) (‘‘The guidelines
require that states provide support for
any site-specific costs that depart from
the generic numbers in the Control Cost
Manual. See 40 CFR part 51 app.
Y(IV)(D)(4)(a) n.15 (‘‘You should
include documentation for any
additional information you used for the
cost calculations, including any
information supplied by vendors that
affects your assumptions regarding
purchased equipment costs, equipment
life, replacement of major components,
and any other element of the calculation
that differs from the Control Cost
Manual.’’)’’) (emphasis added).
Notwithstanding that the BART
Guidelines are mandatory for Laramie
River Station, we agree that Wyoming’s
approach, having used both the actual
NOX emission rate and the actual heat
input from the baseline period, resulted
in a realistic depiction of anticipated
annual emissions consistent with the
BART Guidelines, that these emissions
differed only slightly from baseline
emissions estimated by EPA and that,
therefore, Wyoming’s treatment of
baseline emissions by itself was not a
basis for EPA to disapprove NOX BART
for Laramie River Station. Nonetheless,
as discussed in response to other
comments, we maintain that there were
other deficiencies in Wyoming’s BART
analysis for Laramie River Station that
remain a valid basis for our disapproval.
Most notably, Wyoming did not
consider the visibility impacts of SNCR
as required by the CAA and BART
Guidelines.
Comment: Against its longstanding
30-year history of interpreting and
applying the RHR and Guidelines, EPA
has now embarked on a spate of BART
disapprovals demonstrating that the
agency is now interpreting and applying
the Guidelines and CCM very differently
than it did in the past, and signaling that
EPA has actually decided to reinterpret
the statute and Guidelines without
notice and comment to the states.
EPA is manufacturing requirements in
the Guidelines that do not exist, for the
purpose of abandoning the
administrative structure conferring state
primacy that Congress created with both
the CAA generally and the Regional
Haze Statute in particular. EPA is doing
so by interpreting the BART Guidelines
and CCM as setting forth detailed,
mandatory regulatory requirements that
are not actually in the text, and by
seeking to make any deviation from the
recommendations in the Guidelines or
CCM grounds for voiding states’ BART
choices.
EPA is attempting to convert
recommendations into mandates. This
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new interpretation of the Guidelines
and Cost Manual is erroneous, contrary
to their statutory role, unannounced,
and calculated to federalize BART
decisions by making them all follow
identical paths whether or not local
considerations and costs warrant
separate treatment in control decisions.
Response: Our proposal clearly laid
out the bases for our proposed approval
and disapproval of the State’s BART and
reasonable progress determinations, as
well as other SIP elements. We have
relied on the standards contained in our
regional haze regulations and the
authority that Congress granted us to
review and determine whether SIPs
comply with the minimum statutory
and regulatory requirements.61 To the
extent we have found that the State’s
cost analysis relies on values that do not
conform to applicable requirements of
the Act and regulations, we have
disapproved those elements of the
analysis. To the extent the state has
considered visibility improvement from
potential emissions controls in a way
that is inconsistent with the CAA and
regulations, we have disapproved those
elements of the analysis.
Where, as explained in our proposed
notice and final notice, a state
determines that a less stringent control
technology is the ‘‘best available,’’ as
was the case here with regard to NOX
emissions, the state must justify its
decision by explaining how the BART
factors led it to choose that level of
control over more stringent options. See
70 FR 39170–71. While a state has
significant discretion regarding how to
conduct its BART analysis, EPA must
ultimately ensure that the state has
demonstrated it has a reasoned basis,
consistent with the Act’s requirements,
for determining that a given emissions
control technology is ‘‘the best
available’’ for each source. See
Oklahoma, 723 F.3d at 1208 (‘‘[W[hile
it is undoubtedly true that the statute
gives states discretion in balancing the
five BART factors, it also mandates that
the state adhere to certain requirements
when conducting a BART analysis.’’).
In determining SIP adequacy, we
inevitably exercise our judgment and
61 EPA is responsible for reviewing Statesubmitted SIPs and SIP revisions to ensure that they
‘‘meet[ ] all of the applicable requirements of [the
Act].’’ CAA Section 110(k)(3); see also CAA Section
110(l) (EPA shall not approve SIP revision if it
would interfere with ‘‘any . . . applicable
requirement of this chapter’’); Oklahoma, 723 F.3d
at 1204 (EPA reviews all SIPs to ensure plans
comply with the Act). There is nothing unusual
about regional haze SIPs in this regard—they, like
any other SIPs, must be reviewed by EPA, and may
be approved only if they meet all applicable
requirements of the Act, including provisions
related to visibility. See Oklahoma, 723 F.3d at
1207; North Dakota, 730 F.3d at 756–57.
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expertise regarding technical issues, and
it is entirely appropriate that we do so.
Courts have recognized this necessity
and deferred to our exercise of
discretion when reviewing SIPs. See,
e.g., Connecticut Fund for the Env’t.,
Inc. v. EPA, 696 F.2d 169 (2nd Cir.
1982); Michigan Dep’t. of Envtl. Quality
v. Browner, 230 F.3d 181 (6th Cir. 2000);
Mont. Sulphur & Chem. Co. v. EPA, 666
F.3d 1174, 1190 (9th Cir. 2012) cert.
denied, 133 S. Ct. 409, (2012). Contrary
to the commenter’s assertion, we have
not abandoned the State’s primacy. In
fact, we have approved the vast majority
of the State’s determinations. We are
only disapproving the State’s analyses
and decisions that do not conform to the
CAA and regulations. We are authorized
to do so.
Comment: As early as 1979, EPA
recognized that the regional haze
program is organized around ‘‘goals’’
and ‘‘reasonable progress,’’ and not hard
objective requirements: Section 169A of
the CAA provides for consideration of
the degree or significance of visibility
improvement, costs, energy, and other
factors in applying retrofit controls to
major sources and in making
‘‘reasonable’’ progress toward the
national goal. These provisions indicate
that some flexibility can be allowed in
implementing control programs for
remedying existing impairment and that
priorities can be established.
Thus, while the BART analysis may
include consideration of factors similar
to those applied in a BACT analysis,
BART does not require any threshold
level of control. As EPA acknowledged
in its 2004 re-proposal of the BART
Guidelines, ‘‘for the BART analysis,
there is no minimum level of control
required.’’ 69 FR. 25184, 25219 (May 5,
2004). The RHR’s ‘‘national goal’’ is not
a mandate but, rather, a foundation for
analytical tools to be used by the states
in setting RPGs. The BART Guidelines
were therefore developed to assist states
in making their own BART
determinations by providing analytical
tools. They were not designed or
intended by Congress to impose
inflexible mandates that become
tripwires for EPA to use as a means of
federalizing BART decisions with set
criteria. EPA’s current effort to convert
the Guidelines into something they were
not intended to be is improper and
calculated to shift to EPA authority over
BART determinations that Congress
reserved to the states. ‘‘[A]n agency
cannot create regulations which are
beyond the scope of its delegated
authority.’’ Nagahi v. INS, 219 F.3d
1166, 1169 (10th Cir. 2000). Nor can an
agency reinterpret regulations for that
purpose.
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Congress authorized EPA to provide
guidelines only as to limited aspects of
a state’s BART decision-making process,
and left the majority of that process to
the states’ discretion. Specifically, in the
subsection immediately preceding the
reference to the Guidelines, Congress
directed EPA to conduct a study on
available methods for implementing the
national goal and provide
recommendations to Congress for (1)
‘‘methods for identifying,
characterizing, determining,
quantifying, and measuring visibility
impairment in Federal areas’’; (2)
‘‘modeling techniques (or other
methods) for determining the extent to
which manmade air pollution may
reasonably be anticipated to cause or
contribute to such impairment’’; and (3)
‘‘methods for preventing and remedying
such manmade air pollution and
resulting visibility impairment.’’ CAA
Sections 169A(a)(3)(A)–(C), 42 U.S.C.
7491(a)(3)(A)–(C).
In the next subsection, Congress
directed EPA to promulgate
regulations—but with any regulation of
the states’ BART determinations
confined to those limited areas on
which EPA had been directed to
conduct studies and make a report to
Congress. Specifically, CAA Section
169(b) provides, in pertinent part, that
the regulations ‘‘shall—(1) provide
guidelines to the States, taking into
account the recommendations under
subsection (a)(3) of this section on
appropriate techniques and methods for
implementing this section (as provided
in subparagraphs (A) through (C) of
such subsection (a)(3)), and (2) require
each applicable implementation plan for
a State . . . to contain such emission
limits, schedules of compliance and
other measures as may be necessary to
make reasonable progress toward
meeting the national goal.’’ Id. Sections
7491(b)(1)–(2).
Accordingly, Congress only
authorized EPA to promulgate
regulations or guidelines on the
identification and measurement of
visibility impairment, the methods for
measuring and predicting future
visibility impairment, the methods for
preventing and remedying air pollution
and resulting visibility impairment, and
the CAA’s general requirement that
states develop SIPs to include the BART
and reasonable progress determinations
required by the RHR. Congress did not
authorize EPA to promulgate regulations
or guidelines mandating exactly how
the states should conduct their BART
analyses, and made clear that the
purpose of the guidelines was to
provide ‘‘recommendations’’ to the
states.
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Consistent with the statute and
regulations, the BART Guidelines
contemplate a two-step process: (1) the
‘‘Attribution Step,’’ which consists of
analyzing which sources are
appropriately subject to BART controls;
and (2) the ‘‘Determination Step,’’
which consists of determining, based on
the five statutory BART factors, an
appropriate level of control. 70 FR
39108, 39126; see also Utility Air
Regulatory Group, 471 F.3d at 1335–36
(discussing two-step process). The
Guidelines for the Determination Step
are designed as a ‘‘step-by-step guide’’
for states to identify the ‘‘best system of
continuous emissions control
technology,’’ taking into account the
five BART factors. 70 FR 39127. See also
id. at 39158 (the Guidelines describe a
‘‘process for making BART
determinations’’). They are merely
‘‘helpful guidance’’ for sources other
than power plants with a capacity
greater than 750 MW. Id. at 39108;
Utility Air Regulatory Group, 471 F.3d
at 1339. Yet, even for larger power
plants, the Guidelines are procedural in
nature, setting forth criteria for
evaluating control alternatives, but not
mandating a substantive result. As EPA
acknowledges, to mandate a choice of
technology would infringe on ‘‘those
areas where the Act and legislative
history indicate that Congress evinced a
special concern with insuring that
States would be the decision makers.’’
70 FR 39137. See also id. at 39107 (‘‘The
State must determine the appropriate
level of BART control’’).
The flexibility afforded by the
Guidelines is critical to ensuring that
states maintain primacy in making
BART determinations. When EPA reproposed the Guidelines in 2004, for
example, EPA requested comment on a
sequential process—similar to a BACT
analysis—for considering the five
statutory BART factors. 69 FR 25197–
25198. In the final rule, however, EPA
concluded that ‘‘States should retain the
discretion to evaluate control options in
whatever order they choose, so long as
the State explains its analysis of the
CAA factors.’’ 70 FR 39130. EPA also
expressed that the Guidelines confer
authority on the state to make ‘‘a BART
determination based on the estimates
available for each criterion, and as the
CAA does not specify how the state
should take these factors into account,
the states are free to determine the
weight and significance to be assigned
to each factor.’’ Id. at 39123.
EPA further emphasized the
flexibility inherent in each step of the
BART determination: ‘‘States have
flexibility in how they calculate costs,’’
id. at 39127, and ‘‘have the flexibility to
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5085
develop their own methods to evaluate
model results,’’ id. at 39108. EPA points
out that ‘‘States should have flexibility
when evaluating the fifth [visibility]
statutory factor.’’ Id. at 39129. See also
id. (‘‘Because each Class I area is
unique, we believe States should have
flexibility to assess visibility
improvements due to BART controls by
one or more methods, or by a
combination of methods . . .’’). Even
the presumptive emission limits for
power plants greater than 750 MW ‘‘are
presumptions only; in making a BART
determination, states have the ability to
consider the specific characteristics of
the source at issue and to find that the
presumptive limits would not be
appropriate for that source.’’ Id. at
39134.
Response: EPA agrees that states play
an important role in the regional haze
program. However, EPA disagrees that
this action conflicts with the State’s
statutory role or that this rule is beyond
EPA’s authority. First, the regional haze
program explains that EPA ‘‘shall . . .
require each applicable implementation
plan for a State . . . to contain such
emission limits, schedules of
compliance, and other measures as may
be necessary to make reasonable
progress toward meeting the national
goal.’’ 42 U.S.C. 7491(b)(2). The CAA
makes clear that EPA is statutorily
obligated to reject a SIP that would
‘‘interfere with any applicable
requirement concerning attainment and
reasonable further progress . . . or any
other applicable requirement of this
chapter.’’ 42 U.S.C. 7410(l). Thus the
CAA provides EPA with the authority to
review and reject an inadequate regional
haze SIP. Oklahoma v. EPA, 723 F.3d
1201, 1207 (10th Cir. 2013); North
Dakota v. EPA, 730 F.3d 750 (8th Cir.
2013).
Second, EPA is required to establish
guidelines to ensure that states achieve
the visibility goals set forth in the Act.
42 U.S.C. 7491(b)(1). EPA agrees that
states have some flexibility in BART
determinations, but that flexibility is
limited and states must provide EPA
with reasoned analysis for their SIP
decisions. Oklahoma v. EPA, 723 F.3d
1201, 1207 (10th Cir. 2013) (noting that
while ‘‘it is undoubtedly true that the
statute gives states discretion in
balancing the five BART factors, it also
mandates that the state adhere to certain
requirements when conducting a BART
analysis’’); North Dakota v. EPA, 730
F.3d 750 (8th Cir. 2013) (explaining EPA
is not required to ‘‘approve a BART
determination that is based upon an
analysis that is neither reasoned nor
moored to the CAA’s provisions’’). The
regional haze guidelines provide states
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with methods to determine BART that
EPA considers reasonable, although
states may consider methods not
provided for in the guidelines in certain
circumstances. For example, in
explaining a state’s flexibility to
determine costs, the guidelines note that
‘‘if there are elements or sources that are
not addressed by the Control Cost
Manual or there are additional cost
methods that could be used, we believe
that these could serve as useful
supplemental information.’’ 70 FR No.
128 39127. (July 6, 2005). A state,
however, must demonstrate that any
methods it has used to determine BART
that are not found within the guidelines
are reasonable.
EPA may, and has, approved state
BART determinations that do not rigidly
follow the BART guidelines, so long as
the state’s determinations are
reasonable. Here, however, Wyoming’s
methods were inconsistent with the
BART guidelines, unreasonable, and
inconsistent with the CAA’s statutory
and regulatory requirements, as
explained elsewhere in these comments.
Nothing in this rule displaces a state’s
discretion to balance the five factors, if
the state calculates the factors using
reasonable methods that are consistent
with the regulatory and statutory
requirements of the CAA.
Comment: EPA is now construing the
BART Guidelines to treat
‘‘recommendations’’ as ‘‘mandates’’
such that states no longer have the
authority to vary from the
recommendations, however
insignificantly, without finding EPA
disapproving their BART
determinations. Such an interpretation
violates both the plain language of the
CAA and its underlying cooperative
federalism structure. First, Section
169A(b)(2)(A) provides that BART shall
‘‘be determined by the State.’’ 42 U.S.C.
7491(b)(2)(A). Section 169A(g)(2)
provides that states are to determine the
‘‘costs of compliance’’ and the ‘‘degree
of improvement in visibility.’’ Id.
Section 7491(g)(2). Any interpretation
and application of the BART Guidelines
and CCM that has the effect, whether
directly or indirectly, of mandating
particular outcomes or approaches to
reaching a BART determination invades
state authority. States do the cost of
compliance and visibility assessments,
not EPA. Treating recommendations as
mandates has the effect of forcing all
states to follow each recommendation
precisely the same way, effectively
federalizing the BART determination by
affording EPA the authority to employ
the SIP approval process as a means of
forcing all states to take the same
approach required by EPA in all cases
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or find their independent decisions
overruled. This violates the structure
and design by Congress, and conflicts
with the congressional commitment of
the BART decision to the States.
American Corn Growers, 291 F.3d at 7–
10. This problem did not exist when
EPA historically construed the
‘‘recommendations’’ in the Guidelines
to be ‘‘recommendations’’ rather than
mandates, but EPA’s current approach
of identifying deviations from the CCM
or from the ‘‘recommendations’’ of the
Guidelines as ‘‘errors of law’’ destroys
state primacy and thus conflicts with
the plain language of the statute and is
unreasonable and not entitled to
deference.
EPA’s interpretation of the BART
Guidelines violates Section 169A of the
CAA because it also restricts state
discretion in the decision-making
process. It is the states, not EPA, that are
authorized to determine BART. 42
U.S.C. 7491(b). In doing so they are
directed to take into consideration the
five BART factors—costs of compliance,
energy and non-air quality
environmental impacts of compliance,
any existing pollution control
technology in use at the source, the
remaining useful life of the source, and
the improvement in visibility that
would be achieved by the use of control
technology. Id. Section 7491(g)(2). The
states must determine how to balance
these factors, and how much weight to
give each of the factors, on a case-bycase basis.
However, EPA interprets the BART
Guidelines as authorizing it to
disapprove the State’s BART
determination based on alleged
technical failures to follow each and
every paragraph and recommendation in
the Guidelines. By relying on isolated
instances of alleged deviation from the
Guidelines, such an interpretation
totally undermines the State’s
prerogative to determine how to weigh
and balance all factors and therefore
conflicts directly with the statutory
grant of authority to the states to make
BART determinations in accordance
with all five BART factors. Section 169A
does not tell the states how to take the
factors into account, nor does it describe
how each of the factors must be treated.
The provision directing EPA to provide
guidelines to the states, id. Section
7491(b)(1), must be read in concert with
the broad grant of authority and
discretion to states, and does not change
the fundamental thrust of the statute.
EPA’s interpretation that states are
constrained to dot every ‘‘i’’ and cross
every ‘‘t’’ the way EPA insists directly
conflicts with the statute’s grant of
BART decision making authority to the
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states. If the BART Guidelines mean
what EPA claims they mean, the
Guidelines violate the CAA.
Response: As explained elsewhere in
this document, we disagree with the
commenter’s assertions. The CAA does
not give states unlimited discretion to
determine BART; EPA retains the same
supervisory role it has with respect to
any SIP submission. We also disagree
that our proposal is inconsistent with
the American Corn Growers decision.
We have determined that Wyoming
utilized flawed cost assessments and
incorrectly estimated the visibility
impacts of controls. We have
determined these issues resulted in nonapprovable BART determinations for the
units for which we proposed a FIP. We
recognize the State’s broad authority
over BART determinations, and
recognize the State’s authority to
attribute weight and significance to the
statutory factors in making BART
determinations. As a separate matter,
however, a state’s BART determination
must be reasoned and based on an
adequate record. Although we have
largely approved the State’s regional
haze SIP, we cannot agree that CAA
requirements are satisfied with respect
to certain specific BART determinations
and other necessary FIP elements.62
Comment: The BART Guidelines
provide that the ‘‘basis for equipment
costs estimates’’ should be documented.
Id. at 39166. The Guidelines give states
the option of using ‘‘data supplied by an
equipment vendor (i.e., budget estimates
or bids) or by a referenced source (such
as the Cost Manual, fifth Edition,
February 1996, EPA 453/B–96–001).’’
Id.3.
In footnote language, the Guidelines
reiterate that costs should be
documented, including ‘‘any
information supplied by vendors that
affects your assumptions regarding
purchased equipment costs, equipment
life, replacement of major components,
and any other element of the calculation
that differs from the Control Cost
Manual.’’ Id. at 39167 n.15. EPA relies
heavily on this footnote to assert that
states, including Wyoming, have failed
to comply with the Guidelines because
they have not adequately documented
strict compliance with the CCM. This is
an erroneous and unreasonable
interpretation of the Guidelines. When
read in conjunction with the CAAwhich bestows substantial discretion on
the states in making BART
62 The commenter cannot challenge EPA’s duly
promulgated regulations and Guideline. Indeed, the
time for such a challenge has long passed, since the
Guidelines were promulgated July 6, 2005, and
could only have been challenged within 60 days.
70 FR 39,104; 42 U.S.C. 7607(b), (d)(1)(J).
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determinations—and other statements
made in the BART Guidelines and the
preamble, this footnote language does
not require states to supply vendor
quotes or other specific information
documenting every single deviation
from the CCM, nor does it confer
authority on EPA to reject a state’s
BART determination when the state
fails to do so. Cf. United Savings Ass’n
v. Timbers of Inwood Forest Assocs.,
484 U.S. 365, 371 (1988) (a provision
read in isolation ‘‘is often clarified by
the remainder of the statutory scheme
. . . because only one of the permissible
meanings produces a substantive effect
that is compatible with the rest of the
law’’); United States v. Boisdore’s Heirs,
49 U.S. 113, 122 (1850) (‘‘[W]e must not
be guided by a single sentence or
member of a sentence, but look to the
provisions of the whole law, and to its
object and policy.’’).
Treating the CCM as a binding
checklist conflicts with the CAA, both
in a general sense, by attempting to
mandate exactly how a state must
evaluate and apply the five BART
factors, and in a specific sense, by
excluding certain costs from
consideration in a BART analysis in the
face of statutory language mandating
that BART be determined based on the
actual ‘‘costs of compliance,’’ not some
artificial costs of compliance. As to the
first issue, EPA itself has recognized
that the CCM is ‘‘a good reference tool,’’
which can be supplemented ‘‘if there
are elements or sources that are not
addressed by the Control Cost Manual
or there are additional cost methods that
could be used.’’ 70 FR at 39127. ‘‘States
have flexibility in how they calculate
costs,’’ which is not appropriately
circumscribed by recommendations set
out in a non-binding manual. See id. See
also id. at 39153 (States retain discretion
in considering ‘‘a number of the factors
set forth in section 169A(g)(2), including
the costs of compliance’’). As to the
second issue, EPA cannot cite to or rely
upon the CCM to challenge any decision
by the states taking into account actual
rather than theoretical costs, because the
statute requires that real costs be
considered. CAA Section 169A(g)(2), 42
U.S.C. 7491(g)(2). The CCM does not
impose binding obligations on states
undertaking BART determinations, and
failure to comply with its overly general
and non-source specific
recommendations is not grounds for
rejection of a state’s analysis of the costs
of compliance.
Additionally, the CCM has not been
subject to notice and comment under
the APA, 5 U.S.C. 701–706; it has not
been published in the Code of Federal
Regulations (CFR); and it is not formally
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incorporated by reference into the BART
Guidelines. Therefore, it is merely a
policy statement that is not binding on
the states. Furthermore, simply
referencing the CCM in the BART
Guidelines is not adequate to make that
non-binding guidance document legally
enforceable. ‘‘Agency statements ‘having
general applicability and legal effect’ are
to be published in the Code of Federal
Regulations.’’ NRDC v. EPA, 559 F.3d
561, 564 (D.C. Cir. 2009), citing 1 CFR
8.1(a). See also Brock v. Cathedral Bluffs
Shale Co., 796 F.2d 533, 539 (D.C. Cir.
1986) (‘‘The real dividing point between
regulations and general statements of
policy is publication in the Code of
Federal Regulations, which the statute
authorizes to contains only documents
‘having general applicability and legal
effect . . .’ ’’) (emphasis in original).
Accordingly, EPA’s assertion that a state
has failed to comply with the BART
Guidelines by using costing
methodology other than that set forth in
the CCM is contrary to federal law and
is arbitrary and capricious.
Federal regulations require that in
order for material to be formally
incorporated by reference into the
Federal Register and the CFR, EPA must
seek approval from the Director of the
Federal Register. 1 CFR 51.1. Documents
are eligible for incorporation only if
they meet certain criteria; incorporation
of a document ‘‘produced by the same
agency that is seeking its approval’’ is
generally inappropriate unless the
Director of the Federal Register finds
that the document also ‘‘possess[es]
other unique or highly unusual
qualities.’’ Id. Section 51.7(a)–(b).
Furthermore, language incorporating a
publication by reference must be ‘‘as
precise and complete as possible,’’
including a statement that the document
is ‘‘incorporated by reference’’ and
‘‘[i]nform[ing] the user that the
incorporated publication is a
requirement.’’ Id. Section 51.9(b)(1), (3).
Finally, dynamic incorporations into the
CFR are prohibited. Id. Section 51.1(f)
(‘‘Incorporation by reference of a
publication is limited to the edition of
the publication that is approved. Future
amendments or revisions of the
publication are not included.’’). See also
76 FR 33590, 33593 (June 8, 2011)
(OSHA noting that ‘‘it cannot
incorporate by reference the latest
editions of consensus standards without
undertaking new rulemaking because
such action would . . . deprive the
public of the notice-and-comment
period required by law’’).
EPA has not complied with the
requirements for incorporating the CCM
into the regulations directing states to
undertake BART Determinations or into
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the BART Guidelines. The regulations
make no mention of the CCM. The
BART Guidelines reference the CCM,
but do not indicate that EPA was
seeking approval for incorporation by
reference; and, in any event, it is
unlikely that the CCM meets the
requirements for incorporation by
reference. Additionally, the Guidelines
reference the 5th edition of the CCM but
direct states to use the most recent
version of the CCM, 70 FR 39167 n.14,
and dynamic incorporation is expressly
prohibited by the regulations governing
incorporation by reference, 1 CFR
51.1(f). Where EPA has failed to comply
with the requirements for incorporation
by reference, the referenced material is
‘‘ineffective to impose obligations upon,
or to adversely affect’’ third parties.
NRDC v. Train, 566 F.2d 451, 457 (D.C.
Cir. 1977). Therefore, the CCM does not
constitute binding law, and EPA has no
authority to reject Wyoming’s BART
determinations on grounds the State
allegedly strayed from the CCM’s cost
methodology.
Response: EPA disagrees with this
comment. First, with regards to noticeand-comment procedures, the BART
Guidelines, including the references
within them to the Control Cost Manual,
have gone through appropriate public
comment procedures and the time to
challenge the BART Guidelines’
references to the CCM has passed. If the
commenter believes the BART
Guidelines improperly incorporated by
reference the CCM, the commenter
could have requested judicial review
within 60 days of the publication of the
BART Guidelines in the Federal
Register. We note that the BART
Guidelines have indeed been published
in the Code of Federal Regulations, in
Appendix Y to Part 51 of Title 40. In
addition, the reference to the CCM in
Appendix Y provides adequate notice to
the public that EPA intended the most
recent version of the CCM to be used,
and provides a link to the CCM itself.
Moreover, the very action that we are
completing today has gone through
notice-and-comment procedures. Thus,
the public has had full opportunity to
comment on our application of the
CCM. Furthermore, the commenter’s
arguments that incorporation by
reference is necessary for anything with
binding legal effect miss the mark. The
BART Guidelines do not contain a
legally binding requirement to use the
CCM, because as we explain next, the
Guidelines clearly state that states may
deviate from the CCM.
Commenter mischaracterizes EPA’s
use and application of the Control Cost
Manual. EPA’s revised costeffectiveness values are consistent with
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CAA and RHR requirements. EPA
explained in issuing the BART
Guidelines that ‘‘[s]tates have flexibility
in how they calculate costs.’’ See 70 FR
at 39127 (July 6, 2005). A state may
deviate from the Control Cost Manual
provided its analysis is reasonable and
the deviations are documented. Here, as
discussed elsewhere in this document,
Wyoming’s cost-effectiveness values
were not reasonable. We disagree with
commenter’s view that our cost analysis
is improper, but we agree that the CCM
is not the only source of information for
the BART analysis. For instance, the
reference to the CCM in the BART
Guidelines clearly recognizes the
potential limitations of the CCM and the
need to consider additional information
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The basis for equipment cost estimates also
should be documented, either with data
supplied by an equipment vendor (i.e.,
budget estimates or bids) or by a referenced
source (such as the OAQPS Control Cost
Manual, Fifth Edition, February 1996, EPA
453/B–96–001). In order to maintain and
improve consistency, cost estimates should
be based on the OAQPS Control Cost Manual,
where possible. The Control Cost Manual
addresses most control technologies in
sufficient detail for a BART analysis. The
cost analysis should also take into account
any site-specific design or other conditions
identified above that affect the cost of a
particular BART technology option.63
As to unusual circumstances, the
BART Guidelines call for
‘‘documentation’’ to be provided for
‘‘any unusual circumstances that exist
for the source that would lead to costeffectiveness estimates that would
exceed that for recent retrofits,64 which
as discussed elsewhere in this final
notice were not provided.
Comment: If EPA is making a BART
determination as part of a FIP, it must
comply with the RHR. Section
169A(g)(2) requires the BART
determination to take into consideration
five statutory factors. These factors
‘‘were meant to be considered together’’
to arrive at a single judgment: a BART
emission limit. Am. Corn Growers, 291
F.3d at 6. EPA’s proposed FIP, however,
does not present a discussion, finding,
or evaluation of the five statutory factors
taken together. Instead, EPA merely
states that it proposes to find that
Wyoming’s BART analysis fulfills all of
the BART requirements except as to
cost-effectiveness and visibility benefits.
EPA then proposes to engraft onto
Wyoming’s consideration of the five
statutory BART factors its own costeffectiveness and visibility analysis, to
arrive at the conclusion that SCR is
63 70
64 70
FR 39104, 39166.
FR 39104, 39168.
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BART. This fails to comply with the
statute. The selection of the BART
emission limit is arrived at by
considering all five BART factors taken
together. This requires, for example, that
the selection of SCR as BART represents
an acceptable balancing of energy and
non-air quality environmental factors.
When Wyoming made this assessment,
however, it was considering LNBs and
OFA, and thus its conclusion—which
EPA proposes to approve—noted that
‘‘combustion control using LNB with
OFA does not require non-air quality
environmental mitigation for the use of
chemical reagents (i.e., ammonia or
urea) and there is a minimal energy
impact.’’ This weighing of statutory
factors does not discuss or apply SCR,
and therefore cannot be adopted by EPA
to support its own BART emissions
limit in its FIP. EPA is therefore
proposing a BART emission limit
without independently considering the
five statutory BART factors, in violation
of Section 169A(g)(2).
Nor does EPA articulate any reasoning
supporting its proposed BART emission
limit that applies all of the statutory
factors. This violates EPA’s obligation to
cogently explain and articulate each
step in its reasoning for proposed
action. State Farm, 463 U.S. at 48 (‘‘[A]n
agency must cogently explain why it has
exercised its discretion in a given
manner.’’). In fact, even as to the costeffectiveness and visibility
improvements EPA relies upon for its
BART emission limit, EPA states that
they are adopted because they are ‘‘in
the range of what EPA has found
reasonable for BART in other SIP and
FIP actions.’’ 78 FR 34776. But EPA
does not identify which ‘‘actions’’ it is
talking about, EPA does not show how
the five factors considered in those
other ‘‘actions’’ make those ‘‘actions’’
comparable this action, and EPA does
not pay even minimal lip service to the
statutory requirement that emission
limits must be based upon local
considerations arrived at by a careful
weighing of statutory factors unique in
each case. EPA is just selecting a
preferred technology (SCR) because it
considers the cost of such technology to
be acceptable to impose upon Basin
Electric, without regard to whether,
when considered for its impacts locally
in Wyoming as Congress intended, it is
the ‘‘best’’ control option for all of the
circumstances fully considered. This
violates five-factor decision-making
process required by the CAA.
Response: We disagree with this
comment. Contrary to commenter’s
assertions, EPA selected the BART
emission limits by considering all five
BART factors taken together and has
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complied with CAA and RHR
requirements. As discussed in our
proposal (see for example discussion
starting at 78 FR 34774) and in our
response to comments in this action (see
sections V.B, V.C, and V.D), we clearly
consider all five factors.
6. Reasonableness Standard
Comment: EPA cannot sidestep the
CAA’s mandate for state discretion by
developing and applying a new
‘‘reasonableness’’ standard for
evaluating and rejecting that discretion.
EPA’s regional haze FIP action,
however, does just that. For example,
EPA incorrectly declared ‘‘the state’s
BART analysis and determination must
be reasonable in light of the overarching
purpose of the regional haze program.’’
(See 78 FR 34743) This overly broad and
illegal ‘‘reasonableness’’ standard allows
EPA to reject any BART determination
that EPA dislikes by merely arguing that
a state’s BART determination is
‘‘unreasonable’’ and without comparing
the state’s determination to any firm or
fixed standards. EPA’s ‘‘reasonableness’’
standard requires statutory and
regulatory limitations on EPA’s
authority to disapprove a reasoned RH
SIP. The fallacy of EPA’s improper
reasonableness standard is made even
more apparent in its application by
EPA, which simply rejects as
‘‘unreasonable’’ many of Wyoming’s
BART-related decisions without offering
sufficient justification of why that is the
case.
In creating and employing its
reasonableness standard, EPA goes to an
even greater extreme by defining
‘‘reasonable’’ in the most self-serving
manner imaginable. In short, EPA
defines ‘‘reasonable’’ to mean that EPA
agrees with the state’s exercise of
discretion, and it defines
‘‘unreasonable’’ to mean EPA does not
agree with the state. (See e.g., 78 FR
34,767, where EPA substitutes its
consideration of costs and visibility
improvement for Wyoming’s). In this
way, EPA attempts to bootstrap itself
into the role of the sole decision-maker
of what is BART and what is not. The
CAA does not countenance such
overreaching by EPA. For all of the
criticism that EPA makes concerning the
state’s analyses, the reality is that the
results of the analyses of both agencies
are very similar. In some cases, EPA’s
numbers (such as the cost of SNCR at
Wyodak) provide less of a justification
for EPA’s chosen BART controls than
Wyoming’s numbers did in its analyses.
However, EPA has used its broad and
unjustified criticisms of the State’s work
to discredit the State’s studies and
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usurp the discretion the State has
applied to its BART determinations.
We also received numerous earlier
comments pertaining to EPA’s use of a
‘‘reasonableness’’ standard for
evaluating BART determinations. For
example, commenters pointed out that
EPA incorrectly declared ‘‘the State’s
BART analysis and determination must
be reasonable in light of the overarching
purpose of the regional haze program.’’
Commenters asserted that the fallacy of
this improper reasonableness standard
is apparent in its application by EPA,
which simply rejects as ‘‘unreasonable’’
many of Wyoming’s BART-related
decisions without offering a sufficient
explanation of why that is the case.
Commenters state that EPA makes no
attempt to explain how any of
Wyoming’s BART determinations are
‘‘unreasonable,’’ but simply decrees that
they are unsupported by any
comparison to any standards,
regulations, or statutes.
Commenters argued that the
reasonableness standard employed by
EPA is not found in the CAA, the RHR,
its Preamble, or Appendix Y.
Commenters go on to point out that
nowhere does EPA define or explain
what constitutes ‘‘reasonable in light of
the overarching purpose of the regional
haze program’’, and that this standard
has not been defined or subjected to
notice and comment rulemaking.
Commenters pointed out that the CAA
does not authorize EPA to adopt and
employ ‘‘a reasonable in light of the
overarching purpose of the regional
haze program’’ criterion for approving
or disapproving a state BART
determination as CAA
Section169A(b)(2)(A) only requires the
State to consider five statutory factors.
Commenters asserted that the CAA does
not impose an additional requirement
that the final BART determination is
‘‘reasonable in light of the overarching
purpose of the regional haze program’’
as determined by EPA and as such
EPA’s imposition of this additional
criterion is therefore lacking in statutory
authority. One commenter stated that
there are no numerical minimums that
emission rates much achieve in a BART
determination and there are no statutory
minimum ‘‘visibility improvement’’
obligations.
One commenter went on to point that
the failure to define how it will
determine reasonableness leads to
inconsistent and subjective agency
action, as illustrated by EPA’s
inconsistent treatment of BART
decisions around the country. The
commenter pointed to BART decisions
in Oklahoma, North Dakota, and Nevada
as examples where EPA’s failure to
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define reasonableness has led to
inconsistent BART decisions.
Another commenter argued that
throughout its proposal, EPA claims to
have reviewed Wyoming’s SIP under a
‘‘reasonableness’’ standard. See, e.g., 78
FR 34776 (‘‘we do not consider
Wyoming’s analyses . . . to be
reasonable’’); see also id. at 34778. EPA
apparently believes that this standard
allows EPA to substitute its judgment
for the State’s whenever EPA generally
alleges that the State’s conclusions or
methods are not reasonable. Yet EPA
cites no statutory or regulatory authority
to support its malleable application of
this ‘‘reasonableness’’ standard of
review. EPA appears to have crafted its
flexible reasonableness standard from
Alaska Department of Environmental
Conservation v. EPA, 540 U.S. 461
(2004). That case stands for the
proposition that EPA has authority to
reject a state decision that ‘‘is not based
on a reasoned analysis[.]’’ Id. at 490
(internal quotation omitted). EPA has
misapplied that standard in its proposal
to disapprove Wyoming’s SIP.
The commenter further argued that
the ADEC standard does not allow EPA
to disapprove SIPs whenever, in EPA’s
opinion, some element of the SIP is not
reasonable. Instead, EPA must provide
SIPs ‘‘considerable leeway’’ and may
not ‘‘second guess’’ state decisions[.]’’
ADEC, at 490 (internal citation omitted).
Accordingly, EPA may disapprove a SIP
under ADEC only by showing that the
SIP is arbitrary. See id. at 490–91. EPA
therefore must defer to the Wyoming’s
determinations in the SIP, and may not
simply substitute its judgment for the
State’s. And, of course, EPA carries the
burdens of production and persuasion
to show that the State acted
unreasonably in light of the statutes and
administrative record. Id. at 494.
The commenter asserted that EPA has
failed to carry those burdens in its
proposed partial disapproval of
Wyoming’s regional haze SIP. The
administrative record demonstrates that
Wyoming’s SIP will achieve the
statutory goal of reasonable progress.
EPA has not shown otherwise. EPA has
shown only that if it had crafted the
implementation plan in the first
instance, it would have done so
differently than Wyoming did. But the
law does not allow EPA to simply
substitute EPA’s preferences for the
State’s. Before EPA can disapprove the
SIP, it must show that the SIP is
arbitrary, in light of the statutes and the
record, and with consideration for the
deference owed the State’s
determinations. For example, with
respect to Jim Bridger Units 1 and 2 the
only meaningful difference in outcomes
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5089
between EPA’s proposed FIP and the
SIP is a roughly five-year period in
which EPA’s proposed controls will
result in lesser emissions, though
without a perceptible visibility
improvement. Save for this distinction,
the SIP and FIP create essentially equal
improvements in visibility. EPA does
not explain why a reduction in NOX
emissions that is more expensive but
not more effective at improving
visibility is more reasonable than the
SIP. That lack of explanation renders
EPA’s proposal arbitrary, and decidedly
‘‘unreasonable.’’
Response: EPA disagrees with this
comment. The CAA requires states to
submit SIPs that contain such measures
as may be necessary to make reasonable
progress toward achieving natural
visibility conditions, including BART.
The CAA accordingly requires the states
to submit a regional haze SIP that
includes BART as one necessary
measure for achieving natural visibility
conditions. In view of the statutory
language, it is logical that the
reasonableness of the State’s BART
analysis and determination would be
evaluated in light of the purpose of the
regional haze program. In addition, our
regional haze regulations, at 40 CFR
51.308(d)(ii), provide that when a state
has established a RPG that provides for
a slower rate of improvement in
visibility than the URP (as has
Wyoming), the state must demonstrate,
based on the reasonable progress
factors—i.e., costs of compliance, time
necessary for compliance, energy and
non-air quality environmental impacts
of compliance, and remaining useful life
of affected sources—that the URP to
attain natural visibility conditions by
2064 is not reasonable and that the
progress goal adopted by the state is
reasonable. 40 CFR 51.308(d)(iii)
provides that, ‘‘in determining whether
the State’s goal for visibility
improvement provides for reasonable
progress towards natural visibility
conditions, the Administrator will
evaluate’’ the state’s demonstrations
under section 51.308(d)(ii). It is clear
that our regulations and the CAA
require that we review the
reasonableness of the State’s BART
determinations in light of the goal of
achieving natural visibility conditions.
This approach is also inherent in our
role as the administrative agency
empowered to review and approve SIPs.
Thus, we are not establishing a new
reasonableness standard, as the
commenter asserts. As we discuss
elsewhere, ADEC supports the use of
this standard, and does not require EPA
to apply a sort of ‘‘arbitrary and
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capricious’’ standard in reviewing
Wyoming’s SIP submittal. The language
regarding the burdens of production and
persuasion in ADEC are inapplicable, as
they refer to a litigation context that is
not present here.
Furthermore, this is a SIP review
action, and we believe that EPA is not
only authorized, but required to exercise
independent technical judgment in
evaluating the adequacy of the State’s
regional haze SIP, including its BART
determinations, just as EPA must
exercise such judgment in evaluating
other SIPs. In evaluating other SIPs,
EPA is constantly exercising judgment
about SIP adequacy, not just to meet and
maintain the NAAQS, but also to meet
other requirements that do not have a
numeric value. In this case, Congress
did not establish NAAQS by which to
measure visibility improvement;
instead, it established a reasonable
progress standard and required that EPA
assure that such progress be achieved.
Here, contrary to the commenter’s
assertion, we are exercising judgment
within the parameters laid out in the
CAA and our regulations. Our
interpretation of our regulations and of
the CAA, and our technical judgments,
are entitled to deference. See, e.g.,
Michigan Dep’t. of Envtl. Quality v.
Browner, 230 F.3d 181 (6th Cir. 2000);
Connecticut Fund for the Env’t., Inc. v.
EPA, 696 F.2d 169 (2nd Cir. 1982);
Voyageurs Nat’l Park Ass’n v. Norton,
381 F.3d 759 (8th Cir. 2004); Mont.
Sulphur & Chem. Co. v. United States
EPA, 2012 U.S. App. LEXIS 1056 (9th
Cir. Jan. 19, 2012).
Finally, regarding commenters’
assertions that we are being
inconsistent, because the comment is
not specific about what aspect of our
proposed disapproval is believed to be
inconsistent with other EPA decisions,
it is not possible for EPA to address in
this response any specific concerns. As
articulated in our proposed rulemaking
and further explained in our responses
to other comments, EPA’s partial
approval and partial disapproval of the
Wyoming regional haze SIP is consistent
with the CAA, the RHR, BART Rule,
and EPA guidance.
Comment: In the absence of criteria or
standards by which ‘‘reasonableness’’
may be assessed, EPA’s claim that the
State’s BART for Laramie River Station
is unreasonable is by definition a mere
subjective conclusion without basis or
foundation. EPA must instead articulate
a standard grounded in the statute by
which it evaluates and disapproves a
SIP and then must support its decision
with a plausible explanation connecting
the facts to its standard.
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Response: The CAA requires states to
submit SIPs that contain such measures
as may be necessary to make reasonable
progress toward achieving natural
visibility conditions, including BART.
The CAA accordingly requires the states
to submit a regional haze SIP that
includes BART as one necessary
measure for achieving natural visibility
conditions. In view of the statutory
language, it is reasonable for the State’s
BART analysis and determination to be
evaluated in light of the purpose of the
regional haze program.
In addition, our regional haze
regulations, at 40 CFR 51.308(d)(ii),
provide that when a state has
established a RPG that provides for a
slower rate of improvement in visibility
than the URP (as has Wyoming), the
state must demonstrate, based on the
reasonable progress factors—i.e., costs
of compliance, time necessary for
compliance, energy and non-air quality
environmental impacts of compliance,
and remaining useful life of affected
sources—that the rate of progress to
attain natural visibility conditions by
2064 is not reasonable and that the
progress goal adopted by the state is
reasonable. 40 CFR 51.308(d)(iii)
provides that, ‘‘in determining whether
the State’s goal for visibility
improvement provides for reasonable
progress towards natural visibility
conditions, the Administrator will
evaluate’’ the state’s demonstrations
under section 51.308(d)(ii). Therefore, it
is clear that our regulations and the
CAA require that we review the
reasonableness of the State’s BART
determinations in light of the goal of
achieving natural visibility conditions.
This approach is also inherent in our
role as the administrative agency
empowered to review and approve SIPs.
Thus, we are not establishing a new
reasonableness standard, as the
commenter asserts.
Here, Wyoming concluded that a limit
of 0.21lb/MMBtu for Laramie River
Station could be achieved with
operation of LNBs with OFA. As
presented in the Introduction section
and elsewhere in the notice, the State’s
regional haze SIP determined that NOX
BART for Laramie River Units 1, 2, and
3 is new LNB/SOFA. We proposed to
disapprove the State’s determination
because the State did not reasonably
assess the costs of compliance and
visibility improvement in accordance
with the BART Guidelines. 78 FR
34766. After revising the State’s costs
and modeling and re-evaluating the
statutory factors, we proposed to
determine that NOX BART is LNB/
SOFA + SCR, with an emissions limit of
0.07 lb/MMBtu for each unit. As the
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result of the comments received on our
proposal, we have further revised our
calculation of the costs of compliance
and visibility modeling. For example, as
explained in the BART section of this
document, we corrected cost estimates
for elevation and provided detailed
comments regarding how site
characteristics were addressed using
available satellite imagery and why this
is a valid approach for providing
estimates that are acceptable for BART
analysis and consistent with CAA and
regulations. While we accepted some of
the revised costs, again as explained in
the BART section of this document, we
did not accept others. For example, we
did not accept cost assumptions where
the necessary supporting documentation
was not provided. After re-evaluating
the BART factors, we continue to find
that LNB/SOFA + SCR is reasonable as
BART and are therefore finalizing our
proposal. As a result, we are finalizing
our proposed disapproval of the State’s
NOX BART determination for Laramie
River Station and finalizing our
proposed FIP that includes a NOX BART
determination of LNB/SOFA + SCR,
with an emission limit of 0.07 lb/
MMBtu (30-day rolling average). The
facts presented here and elsewhere in
our final notice, provided a basis and
foundation, grounded on the CAA and
regulations, for the EPA to reach its
decision regarding the unreasonableness
of Wyoming’s BART for Laramie River
Station.
Comment: EPA attempted to use posthoc, immaterial changes that it
calculated in costs and visibility
improvements to justify usurping
Wyoming’s BART decision-making
authority. This runs counter to the vast
discretion EPA has given to other states’
regional haze SIPs. In Oregon, for
example, despite EPA and Oregon
differing in how each calculated BART
costs that resulted in cost variance of
over $700 per ton, EPA stated that such
difference between the two estimates
would not materially affect Oregon’s
evaluation. The difference between the
cost analyses under EPA’s FIP action
and the Wyoming regional haze SIP
similarly is immaterial. Similarly, in
Colorado, the State’s plan included a
cost analysis that, according to EPA,
was not conducted in accordance with
EPA’s Control Cost Manual. In addition,
EPA explained that Colorado should
have more thoroughly considered the
visibility impacts of controlling
emissions from one BART unit on the
various impacted Class I areas and not
focused on just the most impacted Class
I area. Nevertheless, EPA approved the
State’s SIP, explaining that ‘‘Colorado’s
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plan achieves a reasonable result
overall.’’ EPA should afford Wyoming
the same degree of deference it afforded
Colorado and Oregon. As demonstrated
by the impacts of the Wyoming SIP, it
‘‘achieves a reasonable result overall.’’
EPA’s inconsistency is not just
limited to its disparate actions between
states. In Wyoming, EPA acted
inconsistently in its BART
determinations between sources within
the state. For example, EPA accepted
Wyoming’s cost and visibility BART
analyses for FMC Westvaco and General
Chemical, along with the PM BART
analyses for PacifiCorp’s and Basin
Electric’s BART units. At the same time,
EPA rejected the NOX BART cost and
visibility analyses for PacifiCorp’s and
Basin Electric’s BART units. Wyoming,
however, used the same BART analysis
methodology for those BART units at
which EPA accepted the Wyoming
BART analysis as it did at those BART
units for which EPA did not. By
rejecting some cost and visibility
analyses on the basis that they were
improperly performed, while accepting
others that were performed in the same
manner, EPA acted arbitrarily and
capriciously.
Response: We disagree with this
comment. In evaluating a State’s BART
determination, EPA has the discretion to
develop additional information, such as
cost and visibility analyses. In the end,
this additional information, may
confirm the State’s BART determination
as reasonable, or it may lead EPA to
disapprove the State’s BART
determination as unreasonable.
However, EPA is not required to
develop additional information for all
BART determinations in order to review
the State’s BART determination. If a
State’s BART determination appears to
have reached a reasonable conclusion,
taking into account existing information
and the potential magnitude or effect of
technical flaws in cost or visibility
analyses, EPA may approve the BART
determination. However, if the potential
technical flaws in analyses make it
possible that the State’s BART
determination would be unreasonable,
then EPA may develop additional
information to try to determine whether
the State’s BART determination would
fall within the range of reasonable
outcomes using proper technical
analyses. For example, as we explain
elsewhere in responding to comments
on modeling, in this action EPA was
unable to ascertain the visibility benefits
of individual NOX controls for the
PacifiCorp units from the State’s
modeling because the emission
reductions for multiple pollutants were
modeled together, and therefore we
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were unable to assess the
reasonableness of the State’s BART
determinations.65 Similarly, for the
Basin Electric units, we were unable to
ascertain the visibility benefits of SNCR.
For that reason, we developed
additional modeling. In some cases, the
additional modeling confirmed the
reasonableness of the State’s decisions
while in others it did not.
With respect to the State’s PM BART
determinations, the dollar per ton costs
for higher-than-current levels of control
were generally high (regardless of
potential flaws in determining those
costs), so existing information was
adequate to find that the PM BART
determinations were reasonable. With
respect to FMC Westvaco and General
Chemical, the State’s modeling (which
as we discuss elsewhere used a
conservative estimate of background
ammonia which would tend to result in
an overestimation of visibility impacts)
showed fairly low visibility benefits
from NOX controls. Based on
consideration of the five BART factors,
the State selected combustion controls
for these BART sources. EPA also finds
these determinations reasonable, and
EPA has no reason (nor does the
commenter provide one) to think
otherwise.
With respect to the comments
regarding Oregon and Colorado,
although consistency with similar
determinations is one hallmark of
reasonableness, the BART
determinations are very fact-specific
and cannot be easily compared across
states. For example, in the Oregon
action, EPA noted that (among other
things) the source would shutdown in
2020, so ‘‘it [was] reasonable for the
state to consider the sizable capital cost
difference between [two technologies],
and the relatively small incremental
visibility improvement between the two
technologies.’’ 76 FR 38900. Thus, EPA
could assess on the basis of existing
information that the State’s BART
determination was reasonable. With
respect to the Colorado SIP, we disagree
with the commenter that the Wyoming
and Colorado SIPs would achieve
comparable visibility improvement.
65 As we explain later in this document ‘‘[t]hat is,
since the visibility improvement for each of the
State’s control scenarios was due to the combined
emission reductions associated with SO2, NOX, and
PM controls, it was not possible to isolate what
portion of the improvement was attributable to the
NOX controls alone. For this reason, in the
modeling conducted by EPA, we held SO2 and PM
emission rates constant (reflecting the ‘‘committed
controls’’ for those pollutants identified by
Wyoming), and varied only the NOX emission rate.
This allowed us to isolate the degree of visibility
improvement attributable to the NOX control
option.’’ See response to comments in the modeling
section for further information.
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With respect to consistency generally,
in this action we have considered the
five factors in the context of each
facility. Although one factor (such as
visibility improvement or costs of
compliance) may be similar for a unit in
another state, each factor must be
weighed in the context of the other
source-specific BART factors.
Comment: Section 169A(g)(2) of the
CAA requires states, in determining
BART, to ‘‘take into consideration the
costs of compliance, the energy and
non-air quality environmental impacts
of compliance, any existing air pollution
control technology in use at the source,
the remaining useful life of the source,
and the degree of visibility
improvement which may reasonably be
anticipated to result from the use of
such technology.’’ 42 U.S.C. 7491(g)(2).
The CAA does not require the
achievement of any specific degree of
visibility improvement, and only
requires that a BART determination
eliminate or reduce impairment to
visibility. See id. Section 7491. If the
state’s determination does so, the state
has complied with the statute and
nothing authorizes EPA to propose or
impose its own BART decision.
EPA’s proposed action, however,
articulates a number of additional
grounds that must be met for a SIP to
be ‘‘approvable.’’ These additional
grounds are not found in the text of the
CAA and have never been defined or
promulgated with notice and comment
rulemaking. For example, EPA’s
proposed action articulates a two
pronged test for BART SIP approval:
First, ‘‘a state must meet the
requirements of the CAA and our
regulations for selection of BART’’; and
then second, ‘‘the state’s BART analysis
and determination must be reasonable
in light of the overarching purpose of
the regional haze program.’’ 78 FR
34743.
Basin Electric has no problem with
the first prong of this test, i.e., that a
state’s SIP must ‘‘meet the requirements
of the CAA’’ and ‘‘any [applicable]
regulations’’—so long as those
regulations are confined to the areas
Congress allowed EPA to regulate.
However, the second prong, i.e., that
‘‘the State’s BART analysis and
determination must be reasonable in
light of the overarching purpose of the
regional haze program,’’ sets out a new
‘‘reasonableness’’ obligation that is
neither defined in nor separately set
forth in the Act. Essentially, EPA is
proposing to measure a BART
determination not just against the
statutory criteria but also against EPA’s
own subjective view whether the result
reached is reasonable enough to meet
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the ‘‘overarching goal’’ of the Act. But
since EPA acknowledges that neither
the Act nor the regulations ‘‘mandate
specific milestones or rates of progress,’’
76 FR 58577, EPA’s subjective
reasonable enough requirement imposes
a new legislative standard that either
goes beyond or, for the first time,
purports to define ‘‘the requirements of
the Act.’’ This empowers EPA to
disapprove a state BART determination
and replace it with its own on
reasonableness grounds that have never
been defined or vetted through public
notice and comment.
The same is true with EPA’s assertion
that Wyoming did not provide
‘‘sufficient documentation.’’ 78 FR
34749. EPA is asserting the existence of,
and then a failure to meet, a ‘‘sufficient
documentation’’ requirement that is
both undefined and entirely of EPA’s
own creation. This allows EPA to
extend its regulatory reach to determine
and impose its own view of BART when
a state’s reasoning, according to EPA,
fails to meet unannounced and
undefined legislative criteria. Such an
expansion of EPA’s substantive powers
is illegal. EPA may not employ
evaluative criteria that effectively
extend or define the reach of the CAA
without first subjecting those criteria to
public notice and comment. See, e.g.,
Syncor Int’l Corp. v. Shalala, 127 F.3d
90, 95–96 (D.C. Cir. 1997) (requiring the
FDA to subject a rule that extended its
regulatory reach to notice and comment
before applying it); U.S. Tel. Ass’n v.
FCC, 28 F.3d 1232, 1233–34 (D.C. Cir.
1994) (finding that the FCC’s
application of a new standard was a
substantive rule requiring notice and
comment); Am. Mining Congress v.
Mine Safety & Health Admin., 995 F.2d
1106, 1112 (D.C. Cir. 1993) (outlining
the factors to apply in determining
when a rule is substantive and thus
requires notice and comment).
As the D.C. Circuit Court has
explained, when an agency implements
a substantive change to its regulations
that alters the boundaries of what the
agency can regulate, the change must be
subject to public notice and comment so
that an agency does not expand its
power without public involvement.
Appalachian Power Co. v. EPA, 208
F.3d 1015, 1024 (D.C. Cir. 2000). The
same is true when EPA purports, for the
first time, to vet a state SIP revision
against criteria of its own making not set
forth in the governing statute or the
existing regulations. Here, EPA is
effectively stating that: (1) The most
cost-effective (on a dollar per ton basis)
control technology must be selected as
BART; (2) a state BART determination
must be ‘‘adequately justified,’’
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‘‘sufficiently documented,’’ and
‘‘properly made’’; and (3) the state’s
determination must meet EPA’s
subjective view of ‘‘reasonableness’’ in
reaching the non-binding goal of the
regional haze Program. Each of these
new criteria is outcome determinative,
according to EPA, and each must be met
for the State to be considered in
compliance with Section 169A. As such,
these are new legislative rules that
cannot be adopted and imposed without
first being submitted to notice and
comment rulemaking as required by
CAA Section 307(d), 4207 U.S.C. 7607.
An important indicator of when
public notice is required is that the
change would allow the agency to
extend its own power: ‘‘[A] substantive
rule modifies or adds to a legal norm
based on the agency’s own authority
. . . And, it is because the agency is
engaged in lawmaking that the APA
requires it to comply with notice and
comment.’’ Syncor, 127 F.3d at 95
(emphasis in original). EPA’s current
proposal to disapprove Wyoming’s
BART determination does exactly that.
EPA uses its own authority to modify
the legal norm for reviewing State BART
decisions to give itself the ultimate
authority to impose its own favored
BART standards.
The need for advance rulemaking is
particularly acute when EPA interprets
and applies a statute that itself
establishes no concrete, objective
requirements. No specific rates of
progress, technologies, or visibility
improvements are mandated by the
RHR. Unlike review of a SIP, where EPA
applies specifically defined ambient
concentrations to determine if the SIP
should be approved, there are no
objective criteria against which to
measure the ‘‘reasonableness’’ of any
state BART determination with respect
to cost and visibility judgments.
Under EPA’s self-defined standards,
EPA is left with unfettered discretion to
disapprove any decision with which it
disagrees on the grounds that it is not
‘‘reasonable’’ enough to meet EPA’s
preferences. This is why the law
requires EPA to first define and
promulgate rules explaining what is
‘‘reasonable’’ enough, or what is
‘‘sufficiently documented’’ enough, to
support a BART determination.
Otherwise, EPA can trump state
discretion on the basis of internally
conceived and unexamined evaluative
criteria that extend EPA’s reach without
public involvement.
Response: EPA disagrees with this
comment. First, even assuming that
EPA’s proposed action on the Wyoming
regional haze SIP articulated new
grounds for evaluating a regional haze
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SIP, the proposed action provides the
public with the opportunity to
comment. As evidenced by the
commenter’s submission, the
commenter had the opportunity to
comment on EPA’s approach to
evaluating the Wyoming regional haze
SIP and to identify any concerns
associated with the statement at issue
from our proposal and other aspects of
our action.
Second, the CAA requires states to
submit SIPs that contain such measures
as may be necessary to make reasonable
progress toward achieving natural
visibility conditions, including BART.
The CAA accordingly requires the states
to submit a regional haze SIP that
includes BART as one necessary
measure for achieving natural visibility
conditions. In view of the statutory
language, it is reasonable that the State’s
BART analysis and determination
would be evaluated in light of the
purpose of the regional haze program. In
addition, our regional haze regulations,
at 40 CFR 51.308(d)(ii), provide that
when a state has established a RPG that
provides for a slower rate of
improvement in visibility than the URP
(as has Wyoming), the state must
demonstrate, based on the reasonable
progress factors—i.e., costs of
compliance, time necessary for
compliance, energy and non-air quality
environmental impacts of compliance,
and remaining useful life of affected
sources—that the rate of progress to
attain natural visibility conditions by
2064 is not reasonable and that the
progress goal adopted by the state is
reasonable. 40 CFR 51.308(d)(iii)
provides that, ‘‘in determining whether
the State’s goal for visibility
improvement provides for reasonable
progress towards natural visibility
conditions, the Administrator will
evaluate’’ the state’s demonstrations
under section 51.308(d)(ii). It is clear
that our regulations and the CAA
require that we review the
reasonableness of the State’s BART
determinations in light of the goal of
achieving natural visibility conditions.
This approach is also inherent in our
role as the administrative agency
empowered to review and approve SIPs.
Thus, we are not establishing a new
reasonableness standard, as the
commenter asserts.
As explained above, our proposal
clearly laid out the bases for our
proposed disapproval of the State’s
BART and reasonable progress
determinations, and we have relied on
the standards contained in our regional
haze regulations and the authority that
Congress granted us to review and
determine whether SIPs comply with
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the minimum statutory and regulatory
requirements. In determining SIP
adequacy, we inevitably exercise our
judgment and expertise regarding
technical issues, and it is entirely
appropriate that we do so. Courts have
recognized this necessity and deferred
to our exercise of discretion when
reviewing SIPs.
Finally, we disagree with the
argument that we must approve a BART
determination where the SIP reflects
consideration of the five factors and the
BART selection will result in some
improvement in visibility. We think
Congress expected more when it
required the application of ‘‘best
available retrofit technology.’’
Comment: In 2004, EPA represented
to the United States Supreme Court that
it would act only very rarely to overrule
a state decision selecting control
technology for specific sources. ADEC.
Relying upon this representation to
rebut doubts expressed by the dissent,
the Supreme Court affirmed EPA’s
decision to overrule a BACT decision
made by the State of Alaska on the
grounds that the State’s decision was
not ‘‘reasonable’’ because the record
lacked the information necessary to
support the State’s cost assessment. The
ADEC Court held that EPA could review
state BACT determinations to ascertain
whether they were ‘‘reasonable in light
of the statutory guides and the state
administrative record.’’ Id. at 494.
EPA now relies upon the Supreme
Court’s use of the word ‘‘reasonable’’ in
the BACT context to assume authority to
judge the ‘‘reasonableness’’ of state
BART decisions when reviewing SIP
revisions under Section 110, and thus to
disapprove any BART determination it
considers ‘‘unreasonable’’ ‘‘in light of
the over-arching purpose of the regional
haze program.’’ 78 FR 34743. This
formulation seriously misconstrues and
misstates the Supreme Court’s holding
and runs counter to the CAA’s conferral
of authority on the State in selecting
BART. ‘‘Reasonableness in EPA’s
subjective view’’ cannot be applied as a
rubric for approving state BART
decisions, as it allows EPA to impose its
own BART preferences. Rather than
adhere to the core principles of
cooperative federalism codified in the
RHR by only rarely overruling state
technology choices, EPA instead does
exactly what it represented to the
Supreme Court it would not do—
routinely overrule state
determinations—and it does so under
the rubric of authority to evaluate
‘‘reasonableness’’ on a subjective basis.
Examination of EPA’s action in this
and related BART proceedings around
the country demonstrates that EPA is
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not using the ‘‘reasonableness’’ standard
that was actually approved in ADEC. Far
from endorsing a generic
‘‘reasonableness in EPA’s view’’
standard, the ADEC Court echoed the
language of APA arbitrary and
capricious review and upheld EPA’s
rejection of a State BACT determination
on grounds that the State’s
determination was not supported by the
administrative record. The Court stated
that ‘‘[o]nly when a state agency’s BACT
determination is ‘not based on a
reasoned analysis’ may EPA step in to
ensure that the statutory requirements
are honored,’’ and that the Act
‘‘authorizes EPA to act in the unusual
case in which a state permitting
authority has determined BACT
arbitrarily.’’ 540 U.S. at 490–91; citation
omitted). The Court added that ‘‘EPA
adhered to that limited role here,
explaining why ADEC’s BACT
determination was ‘arbitrary’ and
contrary to [the State]’s own findings.’’
Id. The Court thus held that EPA had
properly exercised its authority to reject
the State’s BACT determination when
the State switched from an initial
finding that a certain technology was
economically feasible to finding that the
same technology was economically
infeasible with ‘‘no factual basis in the
record’’ to support the change. Id. at
496–500.
Here, EPA makes no effort to
formulate and apply a ‘‘reasonableness’’
standard that appropriately preserves
for EPA only the ‘‘limited role’’ of
insuring that a state decision is not
arbitrary and capricious and lacking in
record support. Instead, EPA scours the
record for inconsequential actions taken
by states which it can portray as
‘‘inconsistent with’’ the massively
complex, out-dated, and non-binding
CCM or with the largely advisory
Guidelines so that EPA can declare the
state’s decision to be ‘‘unreasonable’’
and take over the choice of BART
technology. EPA does not demonstrate
any arbitrary or capricious conduct, any
lack of reasoned decision making, or
any other documented failure by the
State to follow the requirements of the
statute, as contemplated by the standard
actually approved in ADEC. As a result,
EPA is not employing the
‘‘reasonableness’’ test properly, and
with that error is arrogating power
Congress left to the States, precisely as
predicted by the ADEC dissent. In state
after state, EPA is now striking down
state BART decisions and cloaking its
disregard for state primacy by adjudging
those decisions as ‘‘unreasonable,’’
purportedly in reliance upon authority
granted by ADEC. But it strains
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credulity for EPA to assert that state
after state is making essentially the same
repeated arbitrary and capricious
decisions, the remedy for which is
almost always mandatory imposition by
EPA of its preferred technology choice:
SCR. EPA’s ‘‘reasonableness’’ test is
therefore fundamentally erroneous. EPA
may not exercise authority ‘‘in a manner
that is inconsistent with the
administrative structure that Congress
enacted into law,’’ ETSI Pipeline
Project, 484 U.S. at 517, by applying a
subjective reasonableness standard to
federalize BART decisions.
Response: We responded to similar
comments elsewhere in this document.
Comment: Because EPA’s proposed
disapproval of Wyoming’s BART
determination for Laramie River Station
is inconsistent with EPA’s prior
approval of other state BART choices,
EPA’s proposed decision is an abuse of
discretion and not entitled to deference
from a reviewing court.
For instance, in a CAA case involving
EPA approval of state Title V programs,
the Ninth Circuit reversed EPA’s
disapproval of one state’s program
where EPA’s decision ‘‘conflict[ed]
substantially with numerous EPA
decisions in other states and localities.’’
W. States Petroleum, 87 F.3d at 282. In
that case, EPA had conditioned final
approval of Washington’s proposed
Title V program on the State’s repeal of
certain insignificant emissions units
(‘‘IEU’’) exemptions. EPA eventually
approved the State’s Title V program,
but disapproved the IEUs exemptions as
inconsistent with the applicable
regulations. Id. at 283. Industry
members and the State challenged
EPA’s disapproval on the basis that
EPA’s decision was inconsistent with its
prior interpretation and application of
the regulations in other states. Id. at
282–83. Specifically, EPA had
condoned the exemption of IEUs from
the permit content requirements of the
regulations in at least eight other state
and local programs. Id. at 283. Based on
this evidence, the Ninth Circuit held
that EPA’s rejection of Washington’s
IEU rules was ‘‘undeniably a change in
agency interpretation.’’ Id. at 284.
Accordingly, EPA was required to
support its change by ‘‘reasoned
analysis,’’ which it did not do. Id. (EPA
‘‘may not depart, sub silentio, from its
usual rules of decision to reach a
different, unexplained result in a single
case’’). The court held that EPA abuses
its discretion where it approves
numerous state programs that include
the very same aspects forming the basis
for EPA’s denial of another state’s
program. Id. at 285.
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Other courts have similarly expressed
that an agency acts arbitrarily and
capriciously when it departs from prior
interpretations or precedent without
adequately explaining the reasons for its
departure. See, e.g., Cnty. of Los Angeles
v. Shalala, 192 F.3d 1005, 1022 (D.C.
Cir. 1999) (‘‘A long line of precedent has
established that an agency action is
arbitrary when the agency offer[s]
insufficient reasons for treating similar
situations differently.’’); Shaw’s
Supermarkets, Inc. v. N.L.R.B., 884 F.2d
34, 41 (1st Cir. 1989) (‘‘Unless an agency
either follows or consciously changes
the rules developed in its precedent,
those subject to the agency’s authority
cannot use its precedent as a guide for
their conduct; nor will that precedent
check arbitrary agency action.’’); Puerto
Rican Cement Co. v. EPA, 889 F.2d 292,
298 (1st Cir. 1989) (noting ‘‘the wellestablished legal doctrine that an agency
‘must either follow its own precedents
or explain why it departs from them’ ’’)
(citation omitted); Int’l Internship
Programs v. Napolitano, 853 F. Supp.2d
86, 94 (D.D.C. 2012) (‘‘[I]f an agency
adopts ‘a new position inconsistent
with’ an existing regulation, or effects ‘a
substantive change in the regulation,’
the agency must comply with the notice
and comment requirements of the
APA.’’) (citation omitted). Moreover,
consistency is a factor to be weighed in
determining how much deference an
agency’s interpretation is entitled to
receive. Good Samaritan Hosp. v.
Shalala, 508 U.S. 402, 417 (1993)
(‘‘[T]he consistency of an agency’s
position is a factor in assessing the
weight that position is due.’’). When an
‘‘Agency’s regulations reflect the
Agency’s own longstanding
interpretation,’’ a court ‘‘will normally
accord particular deference’’ to such
‘‘interpretation of ‘longstanding’
duration.’’ Barnhart v. Walton, 535 U.S.
212, 219–20 (2002). But ‘‘the case for
judicial deference is less compelling
with respect to agency positions that are
inconsistent with previously held
views.’’ Pauley, 501 U.S. at 698. ‘‘An
agency interpretation of a relevant
provision which conflicts with the
agency’s earlier interpretation is
‘entitled to considerably less deference’
than a consistently held agency view.’’
I.N.S. v. Cardoza-Fonseca, 480 U.S. 421,
446 n.30 (1987). See also Watt v.
Alaska, 451 U.S. 259, 273 (1981) (‘‘The
Department [of Interior]’s current
interpretation, being in conflict with its
initial position, is entitled to
considerably less deference.’’); W. States
Petroleum, 87 F.3d at 285 (the court
‘‘need not defer to the EPA because the
EPA has abused its discretion in
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departing from its own prior
standards’’).
Here, EPA has taken an inconsistent
approach in interpreting the RHR, the
Guidelines, and the CCM. In particular,
EPA’s current interpretation of its role
and the states’ role under these
provisions conflicts with its prior, longheld understanding that states serve the
primary role in determining BART and
that EPA should not interfere with the
many judgments that go into making
BART determinations.
More specifically, EPA’s application
of its improper and subjective
‘‘reasonableness’’ standard when
reviewing BART determinations in the
SIP approval process has yielded
inconsistent, and therefore arbitrary and
capricious, results. Here, EPA identifies
what it describes as ‘‘cost and visibility
errors for EGUs’’ in Wyoming’s SIP
sufficient to permit EPA to disapprove
the BART determination for Laramie
River, yet EPA proceeds to approve
other Wyoming BART decisions as
‘‘reasonable’’ ‘‘despite the[se] . . .
errors.’’ 78 FR 34750. Either EPA is
applying the law arbitrarily and
capriciously, or it is simply approving
as ‘‘reasonable’’ only those choices with
which it agrees, either of which is
erroneous. EPA must be reasonably
consistent in reviewing state BART
determinations.
Response: We responded to similar
comments above.
Comment: EPA’s implementation of
the RHR does not satisfy the CAA’s
requirements of consistency. The
conclusions reached by EPA on similar
issues vary from case to case in ways
that cannot be explained by statute,
regulation, or guiding principle. EPA
seems to act on BART determinations
with an eye towards achieving its
desired outcome rather than
implementing the CAA even-handedly.
This is the definition of caprice. States,
regulated entities, and the public are left
guessing as to what will be required in
any given case. Because EPA has been
so inconsistent in the current case and
in its overall administration of the RHR,
its proposal to disapprove Wyoming’s
BART determinations for Laramie River
and to impose a FIP is arbitrary and
capricious and must be abandoned.
Response: We responded to similar
comments above.
7. Reliance on Emission Reductions
Comment: EPA’s regional haze FIP
action is also illegal, arbitrary, and
capricious because it relies upon factors
outside of the BART five-factor analysis.
Nowhere in the five-factor analysis, or
anywhere in the Appendix Y
Guidelines, is there any support for EPA
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using an ‘‘emissions reduction’’ factor.
But this is exactly what EPA has done
in its FIP. For example, EPA cited
‘‘emission reductions’’ as the basis for
the FIP BART NOX decisions for Dave
Johnston Unit 3 (See 77 FR 33052),
Wyodak (See 77 FR 33055) and Laramie
River (See 77 FR 33001), among others.
In doing so, however, EPA failed to
account for the fact that the regional
haze program is not an emissions
reduction program per se, but is a
visibility improvement program.
Additionally, it is improper for EPA
to reject Wyoming’s BART
determinations, which relied upon the
proper balancing of all five BART
factors, and replace those BART
determinations with EPA’s analysis,
which relied upon factors outside the
five-factor analysis, such as emissions
reductions. (See e.g., 77 FR at 33,052.)
Courts have held that when an agency
relies on factors ‘‘which Congress has
not intended it to consider,’’ then such
action is arbitrary and capricious.
Arizona Public Service Co. v. US EPA,
562 F.3d 1116, 1123 (10th Cir. 2009).
Earlier comments asserted that EPA’s
regional haze FIP is also illegal,
arbitrary, and capricious because it
relies upon factors outside of the BART
five-factor analysis. Nowhere in the fivefactor analysis, or anywhere in
Appendix Y, is there any support for
EPA using an ‘‘emissions reduction’’
factor. But this is exactly what EPA has
done. For example, EPA cites ‘‘emission
reductions’’ as the basis for the regional
haze FIP BART NOX decisions for Dave
Johnston Unit 3, Wyodak, and Laramie
River Station, among others. In doing so,
however, EPA fails to account for the
fact that the regional haze program is
not an emissions reduction program per
se, but is a visibility improvement
program.
EPA’s over-reliance on ‘‘emissions
reductions’’ outside of the mandated
BART factors has caused EPA to
overstep the boundaries of the regional
haze program. This is evidenced by the
virtually non-existent visibility
improvements associated with SNCR at
Wyodak and Dave Johnston that EPA
approved because of the associated
emission reductions. Additionally, it is
improper for EPA to reject Wyoming’s
BART determinations, which relied
upon the proper balancing of all five
BART factors, and replace those BART
determinations with EPA’s analysis,
which relied upon factors outside the
five-factor analysis. Courts have held
that when an agency relies on factors
‘‘which Congress has not intended it to
consider,’’ then such action is arbitrary
and capricious. Arizona Public Service
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Co. v. US EPA, 562 F.3d 1116, 1123
(10th Cir. 2009).
Response: We disagree with the
commenter’s characterization of the role
of emission reductions in the BART
analyses. The RHR provides that:
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The determination of BART must be based
on an analysis of the best system of
continuous emission control technology
available and associated emission reductions
achievable for each BART-eligible source that
is subject to BART * * * 66
Thus, the BART Guidelines clearly
contemplate the assessment of emission
reductions.
Emission reductions are a
consideration in calculating both
average and incremental cost
effectiveness in order to evaluate the
cost of compliance (one of the five
factors). 70 FR 39167 and 39168.
Contrary to the commenters’ assertions,
however, our disapproval of Wyoming’s
DEQ’s BART analyses is not ‘‘based’’ on
emission reductions, rather the analyses
was based on the best system of
continuous emission control technology
and associated emission reductions
achievable, as used in developing the
BART factor information. For example,
as discussed elsewhere in this section
and final notice, contrary to the
Guidelines’ admonition that ‘‘cost
estimates should be based on the CCM,
where possible,’’ the control cost
calculations supplied by the utilities
and relied upon by Wyoming included
costs not allowed by the CCM, such as
owner’s costs and Allowance for Funds
Utilized During Construction (AFUDC).
Thus, Wyoming’s consideration of the
‘‘cost of compliance’’ for these units was
not consistent with the Guidelines.
Furthermore, as explained elsewhere in
this document, Wyoming’s
consideration of visibility benefits was
inconsistent with the Guidelines
because the State did not provide
visibility modeling from which the
visibility improvement from individual
controls could be ascertained. EPA’s
analyses comports with the CAA and
RHR requirements; therefore, we did not
consider factors outside the Agency’s
authority.
In regard to EPA’s disapproval of
Wyoming’s BART decisions on five
units, EPA’s decision was based on a
careful weighing of the five factors,
including cost of compliance (average
and incremental) and visibility
improvement. Just because EPA points
out the emission reductions does not
mean that it has cited ‘‘emission
reductions’’ as the only basis for the
regional haze FIP BART NOX decisions
for these units.
66 40
CFR 51.308(e)(1)(ii)(A).
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8. Presumptive Limits
Comment: EPA’s regional haze FIP is
improper because it requires postcombustion NOX controls as BART,
when EPA guidelines make clear that
only combustion controls for NOX are
contemplated. (See e.g. 77 FR at 33,053.)
EPA’s Preamble and other guidance
confirm that the combustion controls of
LNBs and OFA (in some form) are
‘‘BART technology’’ for the BART units.
In the Preamble and the RHR, EPA
stated that, except for cyclone boilers,
the ‘‘types of current combustion
control technology options assumed
include low NOX burners, over-fire air,
and coal reburning.’’ 70 FR 39134; see
also 39,144 (‘‘For all other coal-fired
units, our analysis assumed these units
will install current combustion control
technology.’’) (emphasis added). In fact,
in the Technical Support Document
used to develop the presumptive BART
NOX emissions limits, EPA explained
that the ‘‘methodology EPA used in
applying current combustion control
technology to BART-eligible EGUs’’
included applying ‘‘a complete set of
combustion controls. A complete set of
combustion controls for most units
includes a low NOX burner and over-fire
air.’’ (‘‘Technical Support Document,
Methodology for Developing NOX
Presumptive Limits,’’ EPA Clean Air
Markets Division, pg. 1 (dated June 15,
2005)).
EPA’s Preamble and Appendix Y
identify post-combustion controls for
NOX, such as SCR and SNCR, as ‘‘BART
technology’’ for only ‘‘cyclone’’ units.
EPA made it clear that for ‘‘other units,
we are not establishing presumptive
limits based on the installation of SCR.’’
70 FR 39136. Therefore, EPA’s
presumptive ‘‘BART technology’’ is
LNBs and some type of OFA. EPA
further elaborated in the Preamble on
SCR costs, stating that although ‘‘States
may in specific cases find that the use
of SCR is appropriate, we have not
determined that SCR is generally costeffective for BART across unit types.’’
Id.; see also 40 CFR Part 51, Appendix
Y, Section IV.E.5.67 Because EPA
67 Commenters also suggest that, EPA has
methodically changed or selectively ignored the
requirements from those which were established in
40 CFR Part 51 and Appendix Y, which were
published in 2005. The states’ SIPs, written shortly
after that period, were based on the rules and
guidance provided at that time. Since then,
however, EPA has arbitrarily and continually
changed its interpretation of the regional haze
regulations in order to achieve emission reductions
and other objectives well beyond those allowed by
the regional haze program. Here are a few examples
of how EPA’s position has changed over the past
few years with respect to the guidance given for
determining NOX BART controls.
Appendix Y provides a presumptive BART NOX
rate differentiated by boiler design and type of coal
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5095
improperly requires post-combustion
controls in its regional haze FIP, EPA
should withdraw this requirement and
approve the Wyoming SIP. If EPA
desires to impose post-combustion
controls as BART NOX, it must first
amend Appendix Y through a proper
rulemaking procedure.
Commenters further assert that, when
EPA issued the RHR, it established
presumptive NOX BART limits for
power plants based on EPA’s
conclusions about the cost effectiveness
of certain emissions control
technologies, including SCR and
combustion controls. 70 FR at 39131,
39134–39136. These limits are based on
EPA’s acknowledgment that NOX
controls vary considerably and only in
‘‘relatively rare cases’’ would SCR be
appropriate. 69 FR 25184, 25202 (May 5,
2004). EPA’s own pronouncement on
the cost effectiveness of SCR belie its
finding that SCR is cost effective at
Laramie River Station.
The presumptive limits for NOX are
differentiated by boiler design and type
of coal because NOX control
technologies are not ‘‘one size fits all’’
and cost effectiveness is variable. Id. at
39134. As EPA noted in proposing
presumptive NOX BART limits, ‘‘the
removal efficiencies and costs
associated’’ with NOX controls ‘‘vary
considerably, depending upon the
design and operating parameters of the
particular boiler being analyzed.’’ 69 FR
at 25202. For that reason, EPA proposed
(and ultimately finalized) presumptive
NOX BART limits that would not
require post-combustion controls:
‘‘States should require the lowest
emission rate that can be achieved
without the installation of postcombustion controls’’ because they are
‘‘applicable to most EGUs, are relatively
inexpensive, and are already widely
burned. EPA now requires post-combustion
controls significantly more aggressive than the
presumptive rates prescribed in Appendix Y.
Appendix Y makes distinctions for unit size, with
more aggressive controls targeted at the largest
units. In Wyoming, EPA now proposes to require
SCR on units as small as 160 megawatts. The
preamble to the regional haze rules suggests that 75
percent of the electric generating units would have
BART NOX controls cost between $100 and $1,000
per ton. EPA is now imposing costs, based on its
own calculations, of $3,700 to $6,000 per ton on
100 percent of PacifiCorp’s Wyoming BART-eligible
units.
SCR controls were only expected to be costeffective controls for cyclone units with high NOX
emission rates. EPA is now proposing postcombustion NOX controls on every BART-eligible
unit in Wyoming, including the installation of
eleven SCRs. EPA must stop changing its
interpretations of the regional haze rules and
guidelines that were formalized in 2005 and move
ahead with approving the Wyoming BART analysis
and the regional haze SIP which complies with
those rules and guidelines.
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applied.’’ Id. Indeed, EPA ‘‘recognize[d]
that a small number of the largest power
plants may need to install an SCR unit
to meet this control level. In such
relatively rare cases, a State, at its
discretion, may find SCR to be
appropriate if the source causes
visibility impacts sufficiently large to
warrant the additional capital cost.’’ Id.
(emphasis added).
EPA’s presumptive BART
determinations for coal-fired EGUs of
various boiler configurations
demonstrate that emissions control
devices with an average cost
effectiveness greater than $1,350 per ton
are not cost effective. Sargent & Lundy
analyzed the presumptive BART limits
in EPA’s ‘‘Technical Support Document
for BART NOX Limits for Electric
Generating Units Excel Spreadsheet’’
and EPA’s ‘‘Technical Support
Document—Methodology for
Developing BART NOX Presumptive
Limits,’’ and compiled EPA’s cost
effectiveness thresholds for each boiler
design and coal type. Sargent & Lundy,
‘‘BART Cost Effectiveness Thresholds’’
(Jan. 6, 2010). Exhibit 17 to commenter
0148. The report was prepared to
supplement North Dakota’s BART
determination for Basin Electric’s
Leland Olds Station Units 1 and 2, but
is equally applicable to any BART
determination for coal-fired utility
boilers, including Laramie River Station.
Sargent & Lundy concludes that based
on EPA’s own assumptions about
acceptable cost effective levels, ‘‘a
threshold of $1,350/ton should be used
to establish the cost-effectiveness of
NOX retrofit control technologies.’’ Id. at
12.
Sargent & Lundy’s report
demonstrates that EPA consistently
found control technologies to be cost
effective if the cost of NOX removal was
less than $1,350/ton, and not to be cost
effective if the cost of NOX removal was
greater than $1,350/ton. Id. at Figure 3
and accompanying text. For example,
for all boiler categories other than
cyclone units, SCR had an overall
average cost effectiveness of $1,749/ton
NOX removed and was considered not
to be cost effective. Id. at 11.
Combustion controls at non-cyclone
boilers had an overall average cost
effectiveness of $535/ton NOX removed
and were found to be cost effective. Id.
SCR is not cost effective at Laramie
River Station because it greatly exceeds
the $1,350/ton threshold used by EPA in
its presumptive BART determinations.
EPA’s own flawed cost effectiveness
analysis estimates that installation of
SCR at Laramie River Station would
range from between $3,589 and $3,903
per ton of NOX removed—far above the
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$1,350/ton threshold used in its
presumptive BART determination. 78
FR at 34775–34776. EPA does not
mention its presumptive BART limits in
its proposed disapproval of Wyoming’s
BART determinations, and offers no
explanation for departing from the
presumptive levels and the associated
use of combustion controls. 78 FR at
34772–34777. Moreover, when Sargent
& Lundy estimated costs of SCR at
Laramie River Station based on a
detailed scoping-level study, it found
that costs per ton of NOX removed
would range from $8,531 to $9,048, an
amount seven times greater than the
threshold used in the presumptive
BART determination. Sargent & Lundy
Evaluation, Table 7. See also Section
XVIII.A.
We received numerous comments
earlier that EPA’s regional haze FIP is
improper because the BART units are
meeting the presumptive limits in the
BART guidelines based on the
installation of combustion controls.
Commenters go on to assert that the
BART Guidelines only require the
installation of LNBs/OFA and that EPA
determined in the guidelines that SCR
was generally not cost-effective for
BART. One commenter noted that EPA
has completely ignored the presumptive
BART limits in the proposed action and
that this is contrary to the express
requirements in both the RHR and the
BART Guidelines. The commenter goes
on to say that EPA’s attempt to
completely ignore the BART limits
makes the presumptive BART limits
meaningless and this is contrary to the
requirements of the CAA and the clear
intent of the BART Guidelines. One
commenter asserted that the BART
Guidelines show that an alternative
analysis is required only when a source
cannot meet the presumptive limits, and
that while a state may choose to
establish a limit that is more stringent
than the BART limit, there is nothing in
the BART Guidelines that would require
a state to do so.
Commenters asserted that EPA
adopted the presumptive BART limits to
establish the specific control levels
required for EGUs. Commenters point
out that EPA has not repealed the
presumptive limits from the
promulgated BART Guidelines, but in
this action EPA does not even deign to
acknowledge the existence of the
presumptive limits, as if the
presumptive BART limits were no
longer a binding regulation.
Commenters argued that unless and
until EPA goes through notice and
comment rulemaking to remove the
presumptive emissions limits and
establish other requirements consistent
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with the CAA, then EPA must approve
a state’s BART determination that meets
the presumptive regulatory limits.
Response: We disagree with the
commenters. The CAA states the
following regarding emission limits for
fossil-fuel fired generating power plants
having a total generating capacity in
excess of 750 MW:
In the case of a fossil-fuel fired generating
power plant having a total generating
capacity in excess of 750 megawatts, the
emissions limitations required under this
paragraph shall be determined pursuant to
guidelines, promulgated by the
Administrator under paragraph (1).
EPA disagrees that the CAA mandates
specific control levels (i.e., presumptive
emission limits) for power plants with
a total generating capacity of 750 MW or
greater. Rather, the CAA directed EPA to
develop guidelines for states to establish
BART emission limits, and required that
power plants having a total generating
capacity in excess of 750 MW follow the
guidelines when establishing BART
emission limits. In response, in 2005
EPA promulgated the BART Guidelines,
which provide a detailed description of
how a state must approach the BART
determination process for certain large
EGUs, and required that the
determination of fossil-fuel fired power
plants having a total generating capacity
greater than 750 MW must be made
pursuant to the BART Guidelines. As
such, the plain reading of the CAA
language makes it clear the intent was
to make the BART Guidelines
mandatory for EGUs larger than 750
MW, as opposed to presumptive limits.
Compliance with EPA’s
‘‘presumptive’’ NOX emission limits
does not excuse a state from performing
such an analysis, because the
presumptive limits serve as a floor, not
a ceiling, for BART. Furthermore, the
presumptive limits in the Guidelines do
not supplant the Act’s mandate to
consider the five statutory factors, as
codified in the RHR.68 Additionally,
commenters provide no showing that
the assumptions underlying EPA’s
older, generic calculations
representative of hundreds of plants in
fact represent BART, under current
circumstances, at these particular
plants. Moreover, far from rendering the
68 Given the statutory mandate, a state may only
avoid full consideration of the five statutory factors
if an initial consideration demonstrates that further
analysis is moot—for example, where the state
demonstrates that the subject unit already employs
the ‘‘most stringent control available.’’ 70 FR at
39165. Where these unique circumstances are not
present, a state’s failure to consider the five factors
(for large EGUs, by complying with the BART
Guidelines’ five-step analysis) is grounds for
disapproval. CAA Section 110(k)(3), (l); see
Oklahoma, 723 F.3d at 1207–08.
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presumptive limits ‘‘meaningless,’’
EPA’s interpretation is in fact necessary
to effectuate the purpose of the Haze
Rule. The fundamental purpose of the
BART requirement is to determine the
‘‘best system of continuous emission
control technology available and
associated emission reductions
achievable for each BART-eligible
source.’’ 40 CFR 51.308(e)(1)(ii)(A)
(emphasis added). To allow states to
adopt the presumptive limits without
any assessment of whether those limits
represent the ‘‘best’’ control for a
particular EGU at the time of the
determination would be unreasonable in
light of the overarching purpose of the
Haze Rule and the CAA’s visibility
requirements. The presumptive limits
ensure that states aim to achieve, at a
minimum, the level of emissions
reduction that was available and costeffective at the time the BART
Guidelines were adopted. EPA
elaborated in the BART Guidelines
themselves, clarifying that the Agency
expected states to not only meet, but in
appropriate cases exceed the
presumptive limits: ‘‘While these
[presumptive] levels may represent
current control capabilities, we expect
that scrubber technology will continue
to improve and control costs continue to
decline. You should be sure to consider
the level of control that is currently best
achievable at the time that you are
conducting your BART analysis.’’ 40
CFR part 51, App. Y, at IV.E.4 (emphasis
added). Therefore, EPA’s proposed
rulemaking on the Wyoming regional
haze SIP is not contrary to the
requirements of the CAA and
regulations.
Additionally, for each source subject
to BART, the RHR, at 40 CFR
51.308(e)(1)(ii)(A), requires that states
identify the level of control representing
BART after considering the factors set
out in CAA section 169A(g), as follows:
‘‘[s]tates must identify the best system of
continuous emission control technology
for each source subject to BART taking
into account the technology available,
the costs of compliance, the energy and
non-air quality environmental impacts
of compliance, any pollution control
equipment in use at the source, the
remaining useful life of the source, and
the degree of visibility improvement
that may be expected from available
control technology.’’ 70 FR 39158. In
other words, the presumptive limits do
not obviate the need to identify the best
system of continuous emission control
technology on a case-by-case basis
considering the five factors. A state may
not simply ‘‘stop’’ its evaluation of
potential control levels at the
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presumptive level of control if more
stringent control technologies or limits
are technically feasible. We do not read
the BART guidelines in appendix Y to
contradict the requirement in our
regulations to determine ‘‘the degree of
reduction achievable through the
application of the best system of
continuous emission reduction’’ ‘‘on a
case-by-case basis,’’ considering the five
factors. 40 CFR 51.301 (definition of
Best Available Retrofit Technology); 40
CFR 51.308(e).
Also, our interpretation is supported
by the following language in our BART
guidelines: ‘‘While these levels may
represent current control capabilities,
we expect that scrubber technology will
continue to improve and control costs
continue to decline. You should be sure
to consider the level of control that is
currently best achievable at the time
that you are conducting your BART
analysis.’’ 70 FR 39171.
The presumptive limits are
meaningful as indicating a level of
control that EPA generally considered
achievable and cost effective at the time
it adopted the BART guidelines in 2005,
but not a value that a state could adopt
without conducting a five factor
analysis considering more stringent,
technically feasible levels of control.
Commenters focus on narrow
passages of the BART guidelines to
support their view that the presumptive
limits represent the most stringent
BART controls that EPA can require for
regional haze. However, these passages
must be reconciled with the language of
the RHR cited above, as well as other
passages of the BART guidelines and
associated preamble. A central concept
expressed in the guidelines is that a
state is not required to consider the five
factors if it has selected the most
stringent level of control; otherwise, a
state must fully consider the five factors
in determining BART. 40 CFR part 51,
appendix Y, section IV.D.1, step 1.9.
Undoubtedly, as the commenters
note, the presumptive limits for NOX
represent cost effective controls, but it is
well-understood that limits based on
combustion controls do not represent
the most stringent level of control for
NOX. Thus, a state which selects
combustion controls and the associated
presumptive limit for NOX as BART
may only do so after rejecting more
stringent control technologies based on
full consideration of the five factors.
Our interpretation reasonably reconciles
the various provisions of our
regulations. We have clearly
communicated our views on this subject
in other states, and, following our
interpretation, Wyoming conducted an
analysis of control technologies that
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5097
would achieve a more stringent limit
than combustion controls.
In promulgating a FIP for the
Wyoming BART sources, we arrived at
an emission limit based on
consideration of the five factors.
Contrary to the commenter’s suggestion,
EPA’s BART guidelines do not establish
a presumptive cost effectiveness level
that is a ‘‘safe harbor’’ or ‘‘shield’’ for
state BART determinations, or that EPA,
when promulgating a FIP, may not
exceed in determining BART. Once a
FIP is required, we stand in the state’s
shoes. This is not EPA establishing a
new presumptive limit or national rule;
it is EPA, acting in the State’s shoes,
conducting a reasonable source-specific
consideration of cost and the other
regulatory factors.
9. Compliance With 40 CFR 51.308
Comment: EPA should have judged
Wyoming’s BART determinations on the
basis of whether or not the Wyoming
BART determinations are ‘‘necessary’’ to
make ‘‘reasonable progress.’’ EPA’s
RHRs provide two regulatory paths to
address regional haze. (See 77 FR 30953,
30957 (May 24, 2012).) ‘‘One is 40 CFR
51.308, requiring states to perform
individual point source BART
determinations and evaluate the need
for other control strategies.’’ Id. ‘‘The
other method for addressing regional
haze is through 40 CFR 51.309, and is
an option for nine states termed the
‘Transport Region States’ which
include: . . . Wyoming, . . . By meeting
the requirements under 40 CFR 51.309,
states are making reasonable progress
toward the national goal of achieving
natural visibility conditions for the 16
Class I areas on the Colorado Plateau.’’
Id. Wyoming submitted the Wyoming
regional haze SIPs under Section 309.
Therefore, the requirements of Section
308 only apply to the extent required by
Section 309. Importantly, NOX
emissions and controls under Section
309 are treated differently than NOX
emissions and controls under Section
308. This is because Congress and EPA
purposefully focused Section 309 on
addressing the issue of SO2 emissions,
the predominant cause of regional haze
on the Colorado Plateau in the western
US. By contrast, Section 309 recognizes
that NOX emissions have a significantly
smaller impact on visibility on the
Colorado Plateau. In fact, the WRAP
report estimated that ‘‘stationary source
NOX emissions result in nitrates that
probably cause about 2 to 5 percent of
the impairment on the Colorado
Plateau.’’ Several illustrations in the
WRAP NOX report show that nitrate
emissions have very little impact on
Class I areas in or near Utah and
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Wyoming. The WRAP report also
explains that ‘‘NOX controls will have a
relatively small impact on PM and
visibility in the West.’’
The Wyoming SIP, including BART
determinations for NOX, is consistent
with the WRAP’s NOX information, and
also properly acknowledges the
relatively small impact nitrates from
stationary sources like PacifiCorp’s
BART units have on visibility
impairment in Wyoming. Wyoming’s
SIP, page 62, states that ‘‘the majority of
nitrate stems from mobile sources.’’ The
SIP also explains that in all but one
Class I area ‘‘contributions from other
states and Canada are much larger than
contributions from inside Wyoming.’’
Id. Wyoming correctly determined,
consistent with the WRAP reports and
other data, that controlling NOX
emissions from stationary sources like
PacifiCorp’s BART units would yield
very little visibility improvement in
Wyoming. EPA’s own regional haze
visibility map shows that visibility in
Wyoming is among the best in the
country.
In light of the above information, it is
understandable that Section 309 focuses
on addressing SO2 emissions. Indeed,
WRAP focused their efforts primarily on
SO2 emissions because the research
indicated this pollutant had the greatest
impact on visibility. ‘‘Recommendations
for Improving Western Vistas,’’ authored
by the Grand Canyon Visibility
Transport Commission, (June 10, 1996)
at page 32 (identifying sulfates as ‘‘the
most significant contributor to visibility
impairment’’ from stationary sources).
In a separate action, EPA acknowledged
that Wyoming has complied with the
Section 309’s SO2 requirements and
made great progress towards improving
and protecting visibility as a result. For
all of these reasons, Section 309 takes a
different approach to NOX emissions
than does Section 308, placing much
less emphasis on the need for significant
reductions in NOX emissions and
instead focusing almost all attention and
resources in the western U.S. on
reducing SO2 emissions. EPA’s FIP,
with its incredibly expensive and
unneeded NOX control equipment,
ignored the focus and intent of Section
309 and refused to acknowledge the
discretion available to Wyoming to
balance this information in making its
BART determinations.
Additionally, as a result of the lesser
emphasis in Section 309 on NOX
emissions, Section 51.309(d)(4)(vii)
requires a regional haze SIP to ‘‘contain
any necessary long term strategies and
BART requirements for stationary
source . . . NOX emissions.’’ Section
308, by contrast, does not include a
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similar ‘‘necessary to achieve reasonable
progress’’ threshold for BART. The
difference between the two
requirements is both intentional and
meaningful. If a state like Wyoming
finds that a particular BART
requirement is not ‘‘necessary’’ to make
‘‘reasonable progress,’’ then that BART
requirement should not be required as
part of the regional haze SIP. This
interpretation is supported by EPA’s
own position in Central Arizona Water
Conservancy District v. United States,
990 F.2d 1531 (9th Cir. 1993). There,
‘‘EPA chose not to adopt the emission
control limits indicated by the BART
analysis, but instead to adopt an
emissions limitations standard that
would produce greater visibility
improvement at a lower cost.’’ Id. at
1543. The court agreed with EPA,
stating that ‘‘Congress’s use of the term
‘including’ in Section 7491(b)(2) prior to
its listing BART as a method of attaining
‘reasonable progress’ supports EPA’s
position that it has the discretion to
adopt implementation plan provisions
other than those provided by BART
analyses in situations where the agency
reasonably concludes that more
‘reasonable progress’ will thereby be
attained.’’ Id. This same rationale
applies to the term ‘‘necessary’’ in
Section 309. Therefore, in rejecting
Wyoming’s regional haze SIP and
adopting a FIP, EPA is required to show
that the Wyoming SIP will not achieve
‘‘necessary reasonable progress’’
towards the visibility goal, and EPA’s
FIP will. EPA has failed to provide any
support for such a position.
Other comments suggest that by
meeting the requirements under 40 CFR
51.309, states are making reasonable
progress toward the national goal of
achieving natural visibility conditions
for the 16 Class I areas on the Colorado
Plateau. Wyoming submitted its regional
haze SIPs under section 51.309.
Therefore, the requirements of section
51.308 only apply to the extent required
by section 51.309.
Wyoming’s regional haze SIP is
consistent with WRAP’s NOX
information, and also emphasizes the
relatively small impact nitrates that
stationary sources have on visibility
issues in Wyoming. Wyoming correctly
determined, consistent with the WRAP
reports and other data, that controlling
NOX emissions from stationary sources
like PacifiCorp’s units would yield very
little visibility improvement in
Wyoming. Section 51.309
understandably is intended to focus on
SO2 due to the greater visibility impact
from SO2. In a separate action, EPA
acknowledged that Wyoming has
complied with the section 51.309’s SO2
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requirements and made great progress
towards improving and protecting
visibility as a result.
As a result of the lesser emphasis in
section 51.309 on NOX emissions, 40
CFR 51.309(d)(4)(vii) requires a regional
haze SIP to ‘‘contain any necessary long
term strategies and BART requirements
for stationary source . . . NOX
emissions.’’ Section 51.308, by contrast,
does not contain a similar ‘‘necessary’’
threshold for BART. If a BART
requirement is not ‘‘necessary’’ for a
section 51.309 state, such as Wyoming,
to make ‘‘reasonable progress,’’ then it is
not required as part of the regional haze
SIP. In other words, section 51.309
allows a state even more discretion
because of this ‘‘necessary’’ requirement
than would otherwise be allowed under
section 51.308. Wyoming has authority
to adopt those regional haze SIP
provisions that it believes provide for
‘‘reasonable progress,’’ even when those
plan provisions do not align directly
with BART as that may be determined
under Section 51.308.
40 CFR 51.309(d)(4)(vii) provides that
‘‘[a]ny such BART provisions may be
submitted pursuant to either
51.308(e)(1) or 51.308(e)(2).’’ By using
the permissive term ‘‘may,’’ EPA makes
clear that such a submission, under
either subsection, is voluntary and not
mandatory for section 51.309 states. For
this reason, Wyoming, as a WRAP state,
was never required to comply with 40
CFR 51.308(e)(1)(ii)(A) and is only
required to include whatever BART
NOX determinations are ‘‘necessary,’’ as
determined by the State. If Wyoming’s
section 51.309’s SO2 controls already
provide the adequate level of visibility
improvement and protection, then, by
definition, little or no BART NOX
controls would be ‘‘necessary.’’ EPA has
failed to show how any ‘‘necessary’’
NOX controls were excluded from the
Wyoming regional haze SIP; therefore it
should approve Wyoming’s regional
haze SIP.
Response: We disagree with these
comments. As explained in our
proposed rulemaking for section
51.309(d)(4)(viii), we explained that the
provision ‘‘is intended to clarify that if
EPA determines that the SO2 emission
reductions milestones and backstop
trading program submitted in the
section 51.309 SIP makes greater
reasonable progress than BART for SO2,
this will not constitute a determination
that BART for PM or NOX is satisfied for
any sources which would otherwise be
subject to BART for those pollutants’’
(emphasis added). 70 FR 44169 (Aug. 1,
2005). EPA does not interpret this rule
to mean that there are different BART
requirements for section 308 and 309
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regional haze SIPs. EPA’s rulemaking
made no finding that BART
determinations conducted for a state
submitting a SIP under section 51.309
should be conducted any differently
than a state submitting a FIP under only
section 308. The use of the word
‘‘necessary’’ in section 51.309(d)(4)(viii)
was to explain that some states may
have BART NOX emission limitations,
while others may not. As already
explained elsewhere in proposal and
our response to other comments,
Wyoming did not conduct a proper
evaluation of the five statutory factors,
as required by 40 CFR 51.308(e)(1)(ii)(A)
and section 169A(g) of the CAA.
EPA also disagrees with commenter’s
assertion that a BART submission is
discretionary. 40 CFR 51.309(d)(4)(viii)
is clear in that the implementation plan
‘‘must’’ contain BART requirements.
The proposed rulemaking explained
that the provision that provides that
‘‘[a]ny such BART provisions may be
submitted pursuant to either Section
51.308(e)(1) or 51.308(e)(2),’’ was
included to ‘‘allow States the flexibility
to address these BART provisions either
on a source-by-source basis under
Section 51.308(e)(1), or through an
alternative strategy under Section
51.308(e)(2).’’ 70 FR 44169 (Aug. 1,
2005).
Moreover, EPA’s proposal made clear
that ‘‘[i]n limited circumstances, it may
be possible for a State to demonstrate
that an alternative program which
controls only emissions from SO2 could
achieve greater visibility improvement
than application of source-specific
BART controls on emissions of SO2,
NOX and/or PM. We nevertheless
believe that such a showing will be
quite difficult to make in most
geographic areas, given that controls on
SO2 emissions alone in most cases will
result in increased formation of
ammonium nitrate particles.’’ 70 FR
44169 (Aug. 1, 2005). Wyoming’s RH
SIP does not include a demonstration
that the backstop SO2 trading program
under Section 51.309 achieves greater
visibility improvement than application
of source-specific PM BART controls.
Therefore, Wyoming’s Section 51.309
SIP does not provide the adequate level
of visibility improvement to meet the
BART requirements.
With respect to the relationship of
BART and requirements for reasonable
progress under 40 CFR 51.308, EPA
interprets the reasonable progress
requirements to apply to BART sources.
As explained in our guidance, due to
the similarity of the BART and
reasonable progress factors, states may
reasonably rely on their BART
determinations to show reasonable
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progress for those sources for the first
planning period. However, BART is an
independent requirement of the statute
and the RHR. We have disapproved
certain BART determinations by
Wyoming not due to a failure to make
reasonable progress, but due to a failure
to consider the BART factors
appropriately.
10. Legal Analysis
Comment: We received comments
that the proposed rule is costly and that
preliminary calculations by the State of
Wyoming showed that the BART and
long-term strategies under the proposed
rule will cost over $170 million on an
annualized basis; with total capital cost
will be over $1 billion, and annual
operating costs of nearly $600 million.
Commenters went on to say that since
the rulemaking action will exceed $100
million dollars in annual costs it should
be reviewed according to the standards
established in Executive Orders 12866
and 13563. * * *
Another commenter notes that EPA
has also failed to conduct any analysis
of the impacts under the Unfunded
Mandates Reform Act (UMRA). In
addition to the capital costs of nearly
$750,000,000 for Laramie River Station
alone, the annual operating costs of an
SCR system at Laramie River Station are
over $ 15,000,000. The commenter
asserts that this amount is nearly double
that projected by EPAs expert Andover
of just under ($5,000,000), using
generalized information. These annual
operating costs, on top of the capital
costs, for the three units at Laramie
River Station alone, are significant, and
when coupled with the impacts for the
remaining five PacifiCorp units, far
exceed the thresholds of the UMRA.
The UMRA is designed to ensure that
Congress and federal agencies analyze
the impact of proposed statutes and
regulations on local governments and
other entities before taking action.
Where the estimates indicate at least a
$50 million per fiscal year direct cost of
all intergovernmental mandates, or a
$100 million per fiscal year direct cost
of private sector mandates, an analysis
is required to evaluate the impact on
local governments and private entities,
and if necessary, the mandate must be
funded. Western Minnesota, Missouri
River Energy Services, and the
governmental entities they serve—
together with the others served by the
remaining co-owners of Laramie River
Station—will feel an annual impact in
excess of $50 million per year should
the EPA’s FIP become final. Failure of
EPA to conduct any analysis of the
impact of imposing an unfunded
mandate on the small governmental
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5099
entities served by Laramie River Station,
and the other BART units in Wyoming
shows a blatant disregard for the
regulatory process and protections that
are to be accorded such significant
rulemakings.
Earlier comments argued that the
UMRA has been applied to EPA actions
where the costs to regulated entities in
numerous states have been aggregated.
Based upon this precedent, PacifiCorp
believes that EPA should aggregate all
regional haze compliance costs across
Wyoming, Utah, Colorado and Arizona
for PacifiCorp, which would easily
exceed the $100 million threshold. At a
minimum, EPA should aggregate costs
for EPA’s FIPs in Wyoming and
Arizona, which would also exceed the
$100 million threshold.
Additional earlier comments
suggested that the UMRA requires
federal agencies to identify unfunded
federal mandates. For rules that contain
federal mandates, such as EPA’s
regional haze FIP action requiring
expensive pollution controls, title II of
UMRA requires the agencies to prepare
written statements, or ‘‘regulatory
impact statements,’’ (RIS) containing
specific descriptions and estimates,
including a qualitative and quantitative
assessment of the anticipated costs and
benefits of the mandate. This
requirement is triggered by any rule that
‘‘may result in the expenditure by state,
local, and tribal governments, in the
aggregate, or by the private sector, of
$100,000,000 or more (adjusted
annually for inflation) in any 1
year. . .’’ 2 U.S.C. 1532(a).
When a RIS is required, the agency is
also required to ‘‘identify and consider
a reasonable number of regulatory
alternatives and from those alternatives
select the least costly, most cost
effective, or least burdensome
alternative that achieves the objectives
of the rule’’ or explain why that
alternative was not selected. 2 USCA
Section 1535.
Here, EPA has failed to comply with
the UMRA, arguing that the regional
haze FIP ‘‘does not contain a federal
mandate that may result in expenditures
that exceed the inflation adjusted
UMRA threshold of $100 million.’’ EPA
is wrong. PacifiCorp currently
anticipates spending more than $100
million dollars in at least 2014 ($104
million), 2015 ($175 million), and 2016
($154 million) to comply with EPA’s
regional haze FIP for Wyoming (based
on alternative ‘‘one’’ for the Jim Bridger
plant). If the regional haze compliance
costs imposed by EPA’s proposed FIP in
Arizona and EPA’s approval of the
Colorado regional haze SIP are factored
in, the costs to PacifiCorp in a given
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year would be significantly higher. Also,
when the BART NOX and PM
determinations are approved by EPA for
Utah, these costs to PacifiCorp in a
given year could be much, much higher.
Response: We disagree with this
comment. Under section 202 of the
UMRA, before promulgating any final
rule for which a general notice of
proposed rulemaking was published,
EPA must prepare a written statement,
including a cost-benefit analysis, if that
rule includes any ‘‘Federal mandates’’
that may result in expenditures to State,
local, and Tribal governments, in the
aggregate, or to the private sector, of
$100 million or more (adjusted for
inflation) in any one year. EPA has
determined that this rule does not
contain a Federal mandate that may
result in expenditures that exceed the
inflation-adjusted UMRA threshold of
$100 million (in 1996 dollars) by State,
local, or Tribal governments or the
private sector in any one year. We
estimate that the total annual costs in
the aggregate are approximately $93
million (see Table 1).
Comment: EPA’s regional haze FIP
states that EPA’s proposed action is not
subject to Executive Order 13211,
‘‘Actions Concerning Regulations that
Significantly Affect Energy Supply,
Distribution, or Use’’ (66 FR 28,355
(May 22, 2001)), because the proposed
action ‘‘is not a significant regulatory
action under Executive Order 12866.’’
78 FR 34790. EPA further claims the
proposed regional haze FIP is not a
‘‘significant regulatory action’’ under
Executive Order 12866 because the
‘‘proposed FIP applies to only five
facilities’’ and is ‘‘therefore not a rule of
general applicability.’’ EPA is incorrect,
and should withdraw its regional haze
FIP.
Executive Order 13211 provides that
agencies shall submit a statement of
energy effects for matters ‘‘identified as
significant energy actions.’’ A
‘‘significant energy action’’ is defined as
‘‘any action by an agency . . . that
promulgates or is expected to lead to the
promulgation of a final rule or
regulation . . . that is a significant
regulatory action under Executive Order
12866 or any successor order’’ and
‘‘likely to have a significant adverse
effect on the supply, distribution, or use
of energy’’; or is ‘‘designated by the
Administrator of the Office of
Information and regulatory Affairs as a
significant energy action.’’ Id. Section
4(b) (emphasis added). Executive Order
12866, in turn, which concerns
Regulatory Planning and Review,
defines a ‘‘significant regulatory action’’
as any regulatory action that is likely to
result in a rule that may: (1) Have an
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annual effect on the economy of $100
million or more or adversely affect in a
material way the economy, a sector of
the economy, productivity, competition,
jobs, the environment, public health or
safety, or State, local, or tribal
governments or communities. 58 FR
51735, 51738 (Oct. 4, 1993)
According to PacifiCorp’s current
estimates (excluding allowance for
funds used during construction
(AFUDC)), it will spend more than $100
million dollars in capital costs alone in
2014 ($225 million), 2015 ($139
million), 2017 ($146 million) and 2018
($118 million) to comply with EPA’s
regional haze FIP for Wyoming (based
on alternative ‘‘one’’ for the Jim Bridger
plant). If regional haze compliance costs
currently imposed or approved by EPA
on PacifiCorp’s BART Units in Arizona
and Colorado are factored in, the total
capital cost impacts to PacifiCorp in any
given year would be significantly
higher; increasing to approximately
$246 million in 2014, $190 million in
2015, $168 million in 2016, $181
million in 2017, and $118 million in
2018. Also, because the BART NOX and
PM determinations have not yet been
approved by EPA for PacifiCorp’s BART
Units in Utah, EPA’s ultimate BART
requirements in Utah likely will add
even more costs in overlapping
installation and compliance years, with
total project costs for SCR installations
on PacifiCorp’s Utah units currently
estimated to cost in excess of $150
million per unit to install (again,
excluding AFUDC). Based upon these
basic costs alone, there is no doubt that
EPA’s FIP meets the definition of a
‘‘significant regulatory action.’’ Other
large costs, including those related to
EPA’s BART determinations for Basin
Electric, also should be factored into
this analysis together with PacifiCorp’s
costs because they are part of the same
‘‘sector of the economy.’’ Also, as
demonstrated by PacifiCorp’s July 12,
2012, submittal in this docket, EPA’s
regional haze FIP will have an adverse
effect on the supply and distribution of
electricity within PacifiCorp’s system.
Therefore, EPA’s determination that
Executive Order 13211 did not apply is
incorrect, and arbitrary and capricious.
Moreover, EPA has admitted in the
proposed rule that system-wide
‘‘affordability’’ costs should be part of
the BART analysis. 78 FR 34756.
Because EPA’s FIP is a ‘‘significant
regulatory action,’’ EPA must prepare a
‘‘Statement of Energy Effects’’ for the
Administrator of the Office of
Information and Regulatory Affairs,
Office of Management and Budget. (See
Executive Order 13211, Section 2.)
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Because EPA did not do so, the regional
haze FIP is improper.
Executive Order 12866, in turn, which
concerns Regulatory Planning and
Review, defines a ‘‘significant regulatory
action’’ as any regulatory action that is
likely to result in a rule that may: (1)
Have an annual effect on the economy
of $100 million or more or adversely
affect in a material way the economy, a
sector of the economy, productivity,
competition, jobs, the environment,
public health or safety, or State, local,
or tribal governments or communities.’’
Also, as demonstrated by PacifiCorp’s
July 12, 2012 submittal in this docket,
EPA’s regional haze FIP action will have
an adverse effect on the supply and
distribution of electricity within
PacifiCorp’s system. Therefore, EPA’s
determination that Executive Order
13211 did not apply is incorrect, and
arbitrary and capricious.
Moreover, because EPA’s regional
haze FIP action is a ‘‘significant
regulatory action,’’ before imposing its
regional haze FIP EPA must first prepare
a ‘‘Statement of Energy Effects’’ for the
Administrator of the Office of
Information and Regulatory Affairs,
Office of Management and Budget. Such
a statement must include a ‘‘detailed
statement’’ by the agency concerning
‘‘any adverse effects on energy supply,
distribution, or use (including a
shortfall in supply, price increases . . .)
should the proposal be implemented,’’
and ‘‘reasonable alternatives to the
action with adverse energy effects and
the expected effects of such alternatives
on energy supply, distribution, and
use.’’ Accordingly, based on an analysis
of the relevant factors, EPA’s regional
haze FIP is improper because EPA failed
to conduct the required regulatory
analysis and failed to prepare the
required documentation.
Executive Order 12866, in turn, which
concerns Regulatory Planning and
Review, defines a ‘‘significant regulatory
action’’ as any regulatory action that is
likely to result in a rule that may: (1)
Have an annual effect on the economy
of $100 million or more or adversely
affect in a material way the economy, a
sector of the economy, productivity,
competition, jobs, the environment,
public health or safety, or State, local,
or tribal governments or communities.’’
Response: EPA disagrees that
Executive Order 13211 applies to this
action. Order 13211 is only applicable
to an agency regulation that is a
‘‘significant regulatory action’’ under
Executive Order 12866. Executive Order
13211(4)(b). Order 13211 also explicitly
adopts the definitions of ‘‘regulation’’
and ‘‘rule’’ as explained in Executive
Order 12866. Executive Order
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13211(4)(a). However, this action does
not fit within the definition of Executive
Order 12866, which defines a
‘‘regulation’’ or ‘‘rule’’ as an ‘‘agency
statement of general applicability.’’
Executive Order 12866(3)(d). Here,
EPA’s action was individually tailored
for a limited number of BART eligible
sources in Wyoming and is not
generally applicable. Thus this action is
not governed by Order 12866 and,
therefore, is also not governed by
Executive Order 13211. As discussed in
more detail in Statutory and Executive
Orders Review section of this document,
the costs for this action are about $93
million annually.
Moreover, as explained in more detail
elsewhere, EPA took the cost of
compliance into consideration when
making BART determinations to ensure
this rule’s requirements are beneficial
and not unduly burdensome. The
commenter is correct that EPA may, in
its discretion, consider system
affordability costs beyond the direct
compliance costs on an individual
facility in extraordinary circumstances.
As explained in the Basis for Final
Action section and elsewhere in the
proposed and final actions, we proposed
to approve the State’s BART and
reasonable progress determinations for
Jim Bridger Units 1 and 2, but on a
different basis.69 In response to our
proposal, we received both supportive
and adverse comments regarding
whether the affordability provisions of
the BART Guidelines should apply to
Units 1 and 2. As explained in more
detail in our responses to these
comments, we agree that PacifiCorp did
not make a sufficient showing that it
could not afford to install LNB/SOFA +
SCR on Units 1 and 2 within the fiveyear compliance period. Nevertheless,
we also received new information
regarding the costs of compliance and
visibility benefits associated with Jim
Bridger and have revised our cost
estimates and visibility modeling for all
69 There, we indicated that given the number of
SCR retrofits PacifiCorp had to perform in Wyoming
and in other states, it might not be affordable for
PacifiCorp to install two additional SCRs on Jim
Bridger Units 1 and 2 within the five-year BART
compliance period. We requested additional
information from commenters regarding whether
the affordability provisions of the BART Guidelines
should be applied to Units 1 and 2. In the
alternative, we proposed to find that NOX BART for
Units 1 and 2 was an emission limit of 0.07 lb/
MMBtu (30-day rolling average) based on the
installation of LNB/SOFA + SCR with a compliance
deadline of five years. Under this scenario, we
acknowledged that the cost-effectiveness of LNB/
SOFA + SCR at Units 1 and 2 was within the range
of what EPA and the State itself had found
reasonable in other BART determinations. We also
considered the significant visibility improvement
demonstrated by the State’s modeling to warrant
LNB/SOFA + SCR as BART.
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four units accordingly. Using this
revised information, we re-evaluated the
five BART factors. Ultimately however,
while we believe that these costs and
visibility improvements could
potentially justify LNB/SOFA + SCR as
BART, because this is a close call and
because the State has chosen to require
SCR as a reasonable progress control, we
believe deference to the State is
appropriate in this instance. We are
therefore finalizing our approval of the
State’s determination to require SCR at
Jim Bridger Units 1–4, with an emission
limit of 0.07 lb/MMBtu (30-day rolling
average), as part of its LTS. We also note
that, neither the CAA nor the regional
haze regulations require EPA to
consider costs beyond an individual
facility’s direct compliance costs. 42
U.S.C.A. Section 7491(g)(1), (2); 40 CFR
51.301. Further, nothing in the Order is
to be construed to impair or otherwise
affect the authority granted by law to
EPA, nor does it create any right or
benefit enforceable at law.70
Comment: The EPA’s FIP fails to
account for the significant economic
impacts on small entities as required by
the Regulatory Flexibility Act. The
estimated capital cost alone to install
SCRs at Laramie River Station only is
nearly $750,000,000. For Western
Minnesota and its members the total
impact would result in an increase in
wholesale electric rates of twelve
percent, which includes a ten percent
increase due to the capital costs for
installation of the SCRs and an
additional increase of two percent
annually for operating expenses. The
members of Western Minnesota and
Missouri River Energy Services are
small governmental units, which must
be given consideration under the
Regulatory Flexibility Act.
Under the Regulatory Flexibility Act,
EPA is required to analyze the economic
impact of proposed regulations when
there is likely to be a significant
economic impact on a substantial
number of small entities, and to
consider regulatory alternatives that will
achieve the agency’s goal while
minimizing the burden on small
entities. The certification that EPA has
provided with this proposed rule is
perfunctory at best, and does not seek to
analyze the actual elements required by
the Regulatory Flexibility Act.
70 For example, EO 12866 (Sec. 10, Judicial
review) explicitly states, ‘‘This Executive order is
intended only to improve the internal management
of the Federal Government and does not create any
right or benefit, substantive or procedural,
enforceable at law or equity by a party against the
United States, its agencies or instrumentalities, its
officers or employees, or any other person.’’
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The EPA has wholly failed to conduct
any regulatory flexibility analysis
pursuant to the Regulatory Flexibility
Act, which further demonstrates the
arbitrariness of this proposed FIP. If it
had, it would acknowledge that the
Wyoming SIP for NOX provides a
reasonable alternative that has a far less
significant economic impact on small
entities while providing virtually the
same improvement in visibility.
Response: EPA disagrees with this
comment. Courts have interpreted the
Regulator Flexibility Act to require a
regulatory flexibility analysis only when
a substantial number of small entities
will be subject to the requirements of
the agency’s action. See, e.g., Mid-Tex
Elec. Co-op, Inc. v. FERC, 773 F.2d 327,
342 (D.C. Cir. 1985). The economic
analysis described in the Regulatory
Flexibility Act is not required; however,
if the head of an agency certifies that the
rule will not have a significant
economic impact on a significant
number of small entities. 5 U.S.C.
605(b). As the commenter noted, such
certification was made by EPA and
published in the Federal Register as
required by the act. No other action is
required by EPA because the agency is
not imposing any requirements on small
entities. Here, only a limited number of
entities have incurred compliance
obligations under this action, and none
of those entities are ‘‘small entities.’’
EPA still seeks to minimize the
impact of its actions have on small
entities. EPA sought comments
regarding the economic impact from all
entities affected by this action and
carefully considered all relevant
information. As described elsewhere,
EPA believes that this action is
necessary to achieve the objectives of
the CAA and that the visibility
improvements justify the costs of this
rule, as established in the Act and
implementing regulations.
Comment: The underlying purpose of
Executive Order 12866 (Order) is to
foster a regulatory regime that respects
the role of local government, recognizes
that the private sector is the ‘‘best
engine for economic growth,’’ and
appreciates the need to develop
regulations that do not impose
‘‘unacceptable or unreasonable costs on
society.’’ Exec. Order No. 12,866, 58 FR
51735 (Oct. 4, 1993). The Order requires
agencies that propose a significant
regulatory action to consider a
multitude of quantitative and qualitative
factors during the rulemaking process.
Id.
A ‘‘significant regulatory action’’ is
one in which the resulting rule is likely
to ‘‘[h]ave an annual effect on the
economy of $100 million or more or
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adversely affect in a material way the
economy, a sector of the economy,
productivity, competition, jobs . . . or
State, local, or tribal governments or
communities.’’ 58 FR 51735.
Allow us, by way of example, the
opportunity to outline the significance
that the proposed rule will have on one
of Wyoming’s counties. The Laramie
River Station (Station), one of the five
targeted EGUs under the proposed FIP,
is the largest employer in Platte County.
These are good paying jobs that include
health and retirement benefits for the
Station’s employees. In a rural county
with 8,800 people, where the average
annual household income is $46,916,
there is concern that the use of a control
regime as proposed in the FIP may make
operation of the Station substantially
cost-prohibitive and therefore
jeopardize some of the best jobs in Platte
County. Moreover, the retrofitting
outlined in the proposed rule will likely
increase the electric rates of some of
Wyoming’s most vulnerable citizens.
The Station also provides a significant
source of revenue for Platte County. In
the 2012 Fiscal Year, the Station
provided over $3.7 million in state
assessed taxes. This is a significant
source of revenue for Platte County,
revenue that is needed to sustain
essential government functions, such as
operation of the county jail, maintaining
county roads and bridges, and county
health services. Platte County is but one
example. Each of the other potentially
affected counties (Converse, Lincoln,
and Campbell) share those three
principal concerns: (1) The targeted
EGUs provide a significant source of
employment to county residents, (2)
volatility of electric rates on some of
Wyoming’s most vulnerable citizens,
and (3) the EGUs provide a significant
source of revenue in order to sustain
essential county services.
For these reasons, Wyoming’s County
Commissioners cannot accept EPA’s
conclusion that the proposed rule is not
a significant regulatory action.
Accordingly, because the proposed rule
is a significant regulatory action, it
should be subject to review in
accordance with Executive Order 12866
and, by extension, Executive Order
13563.
Response: Executive Order 13563 is
supplemental to and reaffirms the
principles, structures, and definitions
governing contemporary regulatory
review that were established in
Executive Order 12866 of September 30,
1993. In general, the Order seeks to
ensure the regulatory process is based
on the best available science; allows for
public participation and an open
exchange of ideas; promotes
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predictability and reduces uncertainty;
identifies and uses the best, most
innovative, and least burdensome tools
for achieving regulatory ends; and takes
into account benefits and costs, both
quantitative and qualitative. However,
nothing in the Order shall be construed
to impair or otherwise affect the
authority granted by law to the Agency.
In our review process the cost of
compliance was one of the elements
addressed to ensure that the
requirements to achieve the goals stated
in the CAA were beneficial and not
burdensome to the regulated entity.
Please refer elsewhere in our response
to comments (e.g., Introduction and
BART sections) for a detailed analysis of
the elements required by the CAA and
RHR for BART determinations.
Comment: EPA, through this
proposed rule, fails to recognize, or even
to make an effort to understand, the
burden imposed upon Wyoming and its
local governmental entities. If it had
done so, it would have acknowledged
the fundamental value and attainable
progress derived from Wyoming’s
regional haze SIP. Instead, what EPA
proposes is a disingenuous and poorly
crafted rule that ignores fundamental
realities existing in the counties of
Wyoming, that they are rural,
traditionally low-income, and the
economic drivers are typically limited
to tourism, agriculture, or industry. As
such, the proposed rule would create a
disproportionate impact on those
communities playing host to industry.
‘‘Not in my backyard’’ is simply not
an option for many rural communities.
It therefore poses a fundamental
question of equity, a concern reiterated
in Executive Order 13563. Executive
Order No. 13,563, 76 FR 3821 (Jan. 18,
2011). Concerns regarding equity
require the EPA to consider who is
bearing the cost of the proposed rule.
The bottom line is that increased energy
costs that will result from the proposed
FIP will disproportionately hurt our
local economies.
Additional comments argue that EPA
is required to seek views of appropriate
local officials’ before imposing
regulatory requirements that might
significantly or uniquely affect a
particular governmental entity. EPA
must then seek to minimize any burdens
that significantly or uniquely affect the
local governmental entity in a manner
that is consistent with achieving the
underlying regulatory objective.
Response: EPA disagrees with this
comment. Executive Order 13563 is
supplemental to and reaffirms the
principles, structures, and definitions
governing contemporary regulatory
review that were established in
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Executive Order 12866. Executive Order
13563 Section 1(b). In general, the Order
seeks to ensure the regulatory process is
based on the best available science;
allows for public participation and an
open exchange of ideas; promotes
predictability and reduces uncertainty;
identifies and uses the best, most
innovative, and least burdensome tools
for achieving regulatory ends; and takes
into account benefits and costs, both
quantitative and qualitative. However,
nothing in the Order shall be construed
to impair or otherwise affect the
authority granted by law to EPA, nor
does it create any right or benefit
enforceable at law. Executive Order
13563 Section 7(b), (d). Each BART
source was examined and the cost of
compliance was one of the factors
addressed to ensure the rule’s
requirements are beneficial and not
unduly burdensome to the regulated
entities. We also note the following: (1)
There will likely be beneficial effects on
tourism due to improved visibility at the
Class I areas; 71 (2) emission controls can
be installed over a period of time; and
(3) in this final action we are mostly
approving the provisions of the State’s
SIP. Moreover, as explained above,
courts have interpreted the Regulatory
Flexibility Act to require a regulatory
flexibility analysis only when a
substantial number of small entities will
be subject to the requirements of the
agency’s action. While EPA has not
made a determination that a substantial
number of small entities will be subject
to the requirements of this final action,
we nevertheless seek to minimize the
impact our actions have on small
entities. EPA sought comments
regarding the economic impact from all
71 Results of visitor surveys from 22 studies
demonstrate that clean air and scenic vistas in
national parks consistently rank as the top priorities
of 90 percent or more of visitors. ‘‘National Park
Service Visitor Values & Perceptions of Clean Air,
Scenic Views & Dark Night Skies 1988–2011,’’
Natural Resource Report NPS/NRSS/ARD/NRR–
2013/632 (Feb. 2013), pp. 16–23 (including specific
studies focused on Wyoming’s national parks).
Additionally, as explained in recent National Park
Service (NPS) and U.S. Forest Service (USFS)
reports, the national parks and U.S. Forest Service
lands are important economic engines for local
communities and businesses, with visitors
generating significant economic activity and
support thousands of jobs. See, ‘‘Economic Benefits
to Local Communities from National Park
Visitation, 2011,’’ National Park Service, Natural
Resource Report NPS/NRSS/ARD/NRR–2013/632
(Feb. 2013) (NPS 2013 Report); and ‘‘National
Visitor Use Monitoring Results, National Summary
Report,’’ USDA Forest Service (May 20, 2013
update). In 2011, the NPS report indicates that nonlocal visitor spending to the national parks in
Wyoming was $621 million, creating more than
9,000 jobs. NPS 2013 Report, p. 26. The Grand
Teton National Park alone had more than 2.5
million visitors who spent $463 million which
created more than 6,000 jobs. NPS 2013 Report, p.
19.
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entities affected by this action and
carefully considered all relevant
information. As described elsewhere,
EPA believes that this action is
necessary to achieve the objectives of
the CAA and that the visibility
improvements justify the costs of this
rule, as established in the Act and
implementing regulations. Please refer
elsewhere for a detailed analysis of the
elements required by our regulations for
BART determinations.
Comment: In imposing these
additional costs the proposed action
will unnecessarily impact power
generation in Wyoming and lead
ultimately to increased utility costs for
Wyoming residents. Along these lines,
we believe the proposed action fails to
comply with Executive Order 13132.
The notice of proposed action states:
‘‘Under Executive Order 13132, EPA
may not issue a regulation that has
federalism implications, that imposes
substantial direct compliance costs, and
that is not required by statute, unless
the federal government provides the
funds necessary to pay the direct
compliance costs incurred by state and
local governments, or EPA consults with
state and local officials early in the
process of developing the proposed
regulation.’’ The notice switches that
standard by concluding: ‘‘This rule will
not have substantial direct effects on the
states, on the relationship between the
national government and the states, or
on the distribution of power and
responsibilities among the various
levels of government, as specified in
Executive Order 13132, because it
merely addresses the State not fully
meeting its obligation to prohibit
emissions from interfering with other
states measures to protect visibility
established in the CAA. Thus, Executive
Order 13132 does not apply to this
action.’’ (78 FR 34790).
The conclusion that Executive Order
13132 does not apply to this action
appears inconsistent with the standard
of the Order. The regulation will impose
substantial direct compliance cost on
local governments and there is no
provision for funding those costs by the
federal government. The Wyoming
Municipal Power Agency (WMPA) is a
joint powers board created by eight
Wyoming municipalities to generate and
transmit electricity for the residents of
those municipalities. Through a
partnership, WMPA and thus each of
those municipalities, own a substantial
interest in the Laramie River Station.
WMPA estimates that the EPA’s
proposal would cost an estimated $600
million for the Laramie River Station.
When costs are imposed upon a facility,
owners of that facility must initially
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bear those costs. Whether the generating
facility is owned 100% by a single
municipality, or shared through a
partnership or cooperative, as a result of
that ownership interest a substantial
direct compliance cost is imposed on
the municipal owners.
Response: EPA disagrees that
Executive Order 13132 applies to this
action. The Order only applies to agency
actions that fit within the Order’s
definition of ‘‘policies that have
federalism implications.’’ The Order
defines such actions as rules ‘‘that have
substantial direct effects on states, on
the relationship between the national
government and the States, or on the
distribution of power and
responsibilities among the various
levels of government.’’ Executive Order
13132 Section (1)(a). In contrast, this
action merely addresses Wyoming’s
existing obligations under the CAA and
thus does not impose any additional
burdens beyond that which the law
already requires. Because this rule does
not fit within the definition of ‘‘policies
that have federalism implications,’’ the
Order does not apply to this action.
Moreover, the additional elements of
the standard urged by the commenter do
not apply to this action. EPA must
consult a state or provide funding only
if a regulation that has federalism
implications (1) imposes substantial
direct compliance costs on state and
local governments, and (2) is not
required by statute. Executive Order
13132 Section (6)(b). First, as the
commenter noted, the regulation
imposes compliance costs on Laramie
River Station, not directly on state or
local governments. Municipalities may
possibly be indirectly impacted because
of their membership in WMPA, which
in turn retains a 1.37% ownership
interest in Laramie River Station
through a partnership with the Missouri
Basin Power Project. However, this
action does not impose any direct
compliance costs on local governments.
Second, the CAA requires that states
promulgate adequate SIPs to achieve the
CAA’s visibility goals, and further
requires EPA to promulgate FIPs if a
state fails to meet its obligations. 42
U.S.C. 7492(3)(2), Section 7410(c)(1);
see also WildEarth Guardians v.
Jackson, No. 11–CV–00001–CMA–MEH,
2011 WL 4485964 at *6 (D. Colo. Separt
27, 2011) (finding EPA’s duty to either
approve a state regional haze SIP or
promulgate a FIP is nondiscretionary).
Because this action does not have
federal implications, does not impose
direct compliance costs on local
governments, and is required by statute,
Executive Order 13132 does not apply
to this action.
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Comment: EPA did not properly vet
its proposed FIP against a number of
requirements detailed throughout
Presidential Executive Orders and
within the CAA. Though Presidential
Executive Orders are not binding by
law, they foster an open, transparent
rule-making process. For example,
Executive Order 12866 states, ‘‘The
American people deserve a regulatory
system that works for them, not against
them: a regulatory system that . . .
improves the performance of the
economy without imposing
unacceptable or unreasonable costs on
society.’’ Accordingly, the Order
requires federal agencies, including
EPA, to develop regulations ‘‘in the
most cost effective manner’’ and to
‘‘adopt a regulation only upon a
reasoned determination that the benefits
of the intended regulation justify its
costs.’’ An additional $1.2 billion in
costs under EPA’s proposal in exchange
for no perceptible change in visibility
does not qualify as ‘‘a reasoned
determination that the benefits of the
intended regulation justify its costs.’’
EPA’s proposed action will result in
over $170 million annual adverse
economic impact, well over the $100
million annual threshold identified in
Executive Order 12866. EPA failed to
properly consider material effects its
proposed action will have on the
economy, productivity, competition,
and jobs. By forcing unnecessarily
expensive technologies, electricity rates
will rise even further, putting additional
strain on businesses and millions of
customers that receive electricity from
the generating stations in Wyoming.
Response: EPA disagrees with this
comment. As explained elsewhere, this
action does not fit within the definition
of Executive Order 12866. The Order
defines a ‘‘regulation’’ or ‘‘rule’’ as an
‘‘agency statement of general
applicability.’’ Executive Order
12866(3)(d). Here, EPA’s action was
individually tailored for a limited
number of BART eligible sources in
Wyoming, and thus is not generally
applicable and not governed by Order
12866. Moreover, as explained in more
detail in the BART section, EPA took
the cost of compliance into
consideration when making its BART
determinations to ensure the rule’s
requirements are beneficial and not
unduly burdensome.
11. Consideration of Existing Controls
Comment: Several commenters
asserted that EPA did not properly take
into account the existing pollution
control technology in use at the BARTeligible EGUs, as required by CAA
section 169A(g)(2) and the BART
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Guidelines. These commenters alleged
that EPA was required to consider
updated combustion controls, which
were installed to comply with
Wyoming’s regional haze SIP, by
adjusting the baseline emissions rate for
each facility to account for any
emissions reductions that have been
achieved since the 2001–2003 baseline
period. The commenters suggested that
had EPA relied on available 2011–2012
emissions data, which reflect the NOX
reductions achieved by some of these
newly installed controls, the costeffectiveness values for SNCR and SCR
would have been higher, while the
visibility improvement associated with
SNCR and SCR would have been lower.
For example, one commenter stated
that the baseline emission rate for NOX
in 2001–2003 was 0.27 lbs/MMBtu at
Laramie River, but that the emission rate
had dropped to 0.19 lb/MMBtu after the
installation of over-fire air and low NOX
burners. This commenter asserted that,
had EPA adjusted the baseline to the
latter emission rate, the average costeffectiveness for SNCR would be
between $6,967/ton and $7,014/ton,
while the average cost-effectiveness for
SCR would be between $8,531/ton and
$9,048/ton. Based on these values, the
commenter argued that neither SNCR
nor SCR is cost-effective and therefore
both technologies should be eliminated
as NOX BART for Laramie River.
Another commenter pointed to other
EPA regional haze actions where EPA
adjusted baseline emissions to account
for recently installed controls, such as
EPA’s final actions on the Arizona
regional haze SIP, 77 FR 72512, and
Montana regional haze FIP, 77 FR
57864. This commenter argued that
because EPA had adjusted baseline
emissions for some Arizona and
Montana EGUs to account for controls
recently installed to satisfy consent
decrees obligations or CAA
requirements unrelated to regional haze,
EPA was required to do so for
Wyoming’s EGUs as well.
One commenter submitted additional
comments, after the close of the public
comment period, in response to the
decision of the U.S. Court of Appeals for
the Eighth Circuit in North Dakota v.
EPA, 730 F.3d 750 (8th Cir. 2013). This
commenter again asserted that EPA had
failed to consider the low NOX burners
and over-fire air the commenter had
installed at its facilities to comply with
the Wyoming regional haze SIP. The
commenter argued that EPA’s alleged
failure to consider these controls
violates the holding in North Dakota,
that ‘‘any existing pollution control
technology’’ includes all existing
controls, including those that are
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voluntarily installed by the source.
Moreover, the commenter explained, the
low NOX burners and over-fire air at its
facilities were not voluntary controls
because they were installed to meet
CAA requirements, were federally
enforceable, and were incorporated into
the Wyoming regional haze SIP.
A final commenter also submitted late
comments in response to the decision in
North Dakota and the previous
commenter’s letter. This commenter
argued that the North Dakota decision
does not require EPA to account for
existing controls by factoring their
associated emissions reductions into
baseline emissions. The commenter
explained that using a consistent
baseline prevents certain sources from
claiming credit for minor emission
reduction measures taken in the midst
of the ongoing regional haze planning
process, thereby making more stringent
controls appear less beneficial. The
commenter also explained that the fixed
baseline period of 2001–2003 allows
EPA to make ‘‘apples-to-apples’’
comparisons of the cost-effectiveness
and visibility benefits of evaluated
technologies across all BART sources.
The commenter pointed out that EPA’s
method of evaluating combustion
controls as a BART option, not as part
of the emission baseline, was identical
to the approach that Wyoming and the
sources themselves had taken in their
own BART analyses. The commenter
argued that this approach is correct
because it ensures that the emissions
reductions associated with existing
controls installed after the baseline
period are evaluated in the BART
analysis. It also factors the cost of such
controls into the source’s compliance
costs, rather than assuming that such
costs are zero simply because they
already have been incurred. Finally, the
commenter asserted that even if EPA
were to adjust the baseline emissions for
the EGUs in question, SCR would still
be BART for all of the EGUs.
Response: One of the statutory factors
EPA is to consider is ‘‘any existing
pollution control technology in use at
the source.’’ 42 U.S.C. 7491(g)(2). The
CAA does not specify how states or EPA
must ‘‘take into consideration’’ this
factor. The BART Guidelines provide
little additional guidance, stating only
that ‘‘[f]or emission units subject to a
BART review, there will often be control
measures or devices already in place.
For such emission units, it is important
to include control options that involve
improvements to existing controls and
not to limit the control options only to
those measures that involve a complete
replacement of control devices.’’ 40 CFR
part 51, app. Y, at IV.D.1.6.
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Consequently, we believe that states and
EPA have considerable discretion in
how they consider existing controls in
use at a source, so long as that
consideration is explained and
reasonable. Ultimately, states or EPA
should consider the totality of the
circumstances (e.g., the purpose of any
existing controls, when and why they
were installed, compatibility with other
control options, enforceability, and
other pertinent factors) in determining
how they will evaluate existing controls
in a BART analysis.
For example, one way in which a state
or EPA can consider existing controls,
as contemplated by the BART
Guidelines, is by evaluating whether
additional control options are
technologically compatible with a
source’s existing controls, or whether
the presence of the existing controls
would render the installation of some
additional control options infeasible. In
the case of NOX, the presence of existing
combustion controls at a source, such as
low NOX burners or over-fire air, does
not impact the feasibility of installing
post-combustion controls, such as SNCR
or SCR. Consequently, EPA reasonably
determined in this instance that the
presence of existing combustion
controls at several of the BART-eligible
EGUs would not preclude the
installation of either SNCR or SCR.
Pointing to our regional haze actions
in Arizona and Montana, several of the
commenters asserted that EPA was
required to consider existing controls by
adjusting the baseline emissions of
several sources to account for
reductions achieved after the baseline
period. We disagree. The BART
Guidelines recommend that baseline
emissions should be ‘‘based upon actual
emissions from a baseline period.’’ 40
CFR part 51, app. Y, at IV.D.4.d.1. While
the BART Guidelines allow states or
EPA to adjust baseline emissions to take
into account projections of ‘‘future
operating parameters’’ by making such
assumptions into enforceable limits, id.
at IV.D.4.d.2, the BART Guidelines are
silent as to how reductions resulting
from the post-baseline installation of
controls should be treated. One way to
take account of such reductions is to
update the baseline, as we did in our
regional haze actions for Arizona and
Montana. In those rulemakings, we
determined that updating the baseline
was appropriate because several sources
had recently installed combustion
controls to comply with consent-decree
obligations and acid-rain requirements,
while another source had changed its
coal supply. The fact that these controls
were installed to comply with other
CAA requirements heavily informed
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EPA’s decision to update the sources’
baseline emissions. As we explained in
our Arizona action, however, ‘‘an
‘updated baseline’ might not be
appropriate in all instances. For
instance, if it appeared that controls had
been installed early in order to avoid a
more stringent BART determination, it
would presumably not be appropriate to
use a baseline representing these new
controls.’’ 72 FR 72526.
We believe that this is one such
instance. First, unlike in Arizona and
Montana, the sources did not install the
combustion controls in question to
comply with other CAA requirements.
Rather, as stated above in the comment,
the sources installed the controls to
comply with Wyoming’s selection of
BART in its regional haze SIP. This
distinction is important because, by
their very nature, baseline emissions
should be ‘‘a realistic depiction of
anticipated annual emissions’’ before
the installation of BART. 40 CFR part
51, app. Y, at IV.D.4.d. Thus, while
baseline emissions can take into account
newly installed controls and in some
cases future operating parameters,
baseline emissions still must represent a
pre-BART scenario so that the costeffectiveness and visibility benefits of
all potential BART control options can
be evaluated from a consistent
benchmark. Indeed, it would be passing
strange for EPA to update the
commenters’ baseline emissions to
incorporate emission reductions that
they admittedly achieved to comply
with BART. Doing so would bias EPA’s
analysis of additional control options by
giving the commenters credit for
emissions reductions attributable to
BART, but treating the costs they
incurred to achieve those reductions as
if they had never occurred.
Second, we note that the Wyoming
regional haze SIP did not require
compliance with BART until five years
after EPA’s approval of the SIP. At the
time the sources installed the
combustion controls, EPA had not yet
acted upon Wyoming’s regional haze
SIP, and the sources had no way of
knowing whether EPA would ultimately
approve or disapprove Wyoming’s
BART determinations. Thus, it appears
that the sources’ decision to install the
combustion controls early may have
been motivated by an intent to avoid the
possibility of a more stringent BART
determination by EPA under the theory
now advanced in the comment. To be
consistent with our statements in the
Arizona regional haze action, we believe
that it would have been inappropriate
for EPA to have ‘‘taken into
consideration’’ the newly installed
combustion controls at the commenters’
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facilities by updating the baseline in
this case.
Nonetheless, EPA recognizes that we
must ‘‘take into consideration’’ all
existing controls to comply with the
CAA, and have therefore taken the
sources’ existing combustion controls
into consideration in other ways. For
example, in addition to considering
whether the source’s existing
combustion controls were compatible
with the installation of post-combustion
controls, we also used the source’s
current NOX emission rates when we
evaluated the size, design, and reagent/
catalyst cost of SNCR and SCR. For
example, in the case of Laramie River,
we did not use the baseline emission
rate of 0.27 lbs/MMBtu, but rather the
current emission rate of 0.19 lb/MMBtu
that appropriately reflects the
installation of over-fire air and low NOX
burners. Due to the lower NOX emission
rate, the size of the SNCR and SCR
systems and the amount of reagent/
catalyst necessary to operate them are
lower than if we had simply assumed
the baseline emission rate.
Moreover, we do not believe that our
action is inconsistent with the Eighth
Circuit’s decision in North Dakota. In
our regional haze action for North
Dakota, we refused to consider the
DryFiningTM control technology in use
at Coal Creek Station when we
promulgated a FIP. We argued to the
court that the CAA did not require states
or EPA to consider controls that were
voluntarily installed after the baseline
period. The court rejected this position,
holding that ‘‘EPA’s refusal to consider
the existing pollution control
technology in use at the Coal Creek
Station because it had been voluntarily
installed was arbitrary and capricious.’’
North Dakota, 2013 U.S. App. LEXIS
19442, at*30. The court explained that
‘‘any existing pollution control
technology’’ included even voluntarily
installed controls. However, the court
did not opine as to how existing controls
must be considered. Here, EPA
reasonably considered the existing
controls at the BART-eligible sources in
the several ways described above. North
Dakota does not require us to ‘‘take into
consideration’’ existing controls by
adjusting baseline emissions, which
would have been inappropriate in this
instance.
Finally, while we acknowledge the
supportive comments from the final
commenter on this issue and agree with
many of the points that were made, we
decline to require SCR at all of the
BART-eligible EGUs, for reasons
explained elsewhere in this document.
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12. Consent Decree
Comment: As it had on other SIPs,
EPA neglected to act on Wyoming’s SIP,
and as a result exposed itself to liability
for violating Section 110(k) of the CAA.
See 42 U.S.C. 7410(k)(2), (3) (setting
deadlines for EPA action on SIPs).
Wyoming could have sued EPA for
failing to take action on Wyoming’s SIP,
but in the spirit of cooperation, elected
not to. Instead, special interest groups
sued EPA for its failure to comply with
the Act. See Compl., WildEarth
Guardians v. Jackson, No. 1:11-cv00001–CMA–MEH (D. Colo. Jan. 2,
2011). Wyoming did not participate in
this litigation for two reasons: First,
Wyoming was not aware of the litigation
until EPA published the proposed
consent decree, 76 FR 34983 (June 15,
2011); and, second, EPA has repeatedly
opposed state attempts to participate in
litigation that impacts the processing of
SIPs, see, e.g., Def. Opp. to North
Dakota’s Motion to Intervene, WildEarth
Guardians v. Jackson, No.4:09–CV–
02453–CW (N.D. Cal. Oct. 20, 2011).
The special interest groups’ litigation,
in turn, has driven EPA’s approach to
Wyoming’s SIP. The litigation has
established arbitrary deadlines for EPA
to act on Wyoming’s SIP, which EPA
and the special interest groups have
repeatedly extended for their
convenience. Not once has EPA
consulted the State on these deadlines.
More troubling, through settlement of
that litigation, EPA has committed to
particular courses of action on
Wyoming’s SIP. EPA has cut Wyoming
out of the cooperative federalism
Congress intended to guide the regional
haze program.
This dubious approach to
implementing the CAA harms states.
The unprecedented influence the
special interest groups have exerted
over EPA’s treatment of Wyoming’s SIP,
coupled with EPA’s effort to conceal its
communications with those groups, lead
a reasonable observer to seriously
question the objectivity of EPA’s
proposed action on Wyoming’s SIP.
The commenter also asserted that the
EPA let sue-and-settle tactics pervert
what is typically a cooperative process.
Nongovernmental groups should not be
allowed to coerce an agency into setting
policy as a result of litigation. Wyoming
considers this an attack on states’ rights,
which does nothing to further the
partnership between EPA and
Wyoming, especially when Wyoming
can’t participate in those discussions.
Response: We disagree with
commenter’s assertions. The Act
provides citizens with the right to sue
EPA when EPA fails to meet a statutory
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deadline, 42 U.S.C. 7604(a)(2), and
courts have the authority to establish a
remedy that sets new deadlines and
compels EPA to do what Congress
required. Id. Section 7604(a). When EPA
is confronted with such suits, it is
reasonable and proper for EPA, working
with the Department of Justice, to
decide that it is in the public interest,
and a more efficient use of executive
and judicial branch resources, to settle
such cases rather than litigate them.
Congress recognized that EPA has
authority to settle cases, and directed
EPA to provide public notice and an
opportunity to comment on proposed
consent decrees before finalizing them.
Id. Section 7413(g).
As explained in the Introduction
section of this document, the consent
decree of which the commenter
complains was the result of a citizen
suit that sought to compel EPA to
approve SIPs or promulgate FIPs to meet
long overdue regional haze
requirements.72 The State of Wyoming
did not submit its regional haze
implementation plan in a timely fashion
as required by the CAA and EPA’s
regulations. Facing substantial legal
risk, EPA reasonably negotiated a
settlement resulting in a consent decree
that set new deadlines for EPA to take
actions required by the Act.73 The
Consent Decree was published in the
Federal Register as is required under
the CAA section 113(g) and provided 30
days for public comment. See 76 FR
34983 (June 6, 2011). For Wyoming,
EPA’s obligations to fully approve SIPs
or promulgate a FIP were now due six
years after the original 2007 deadline for
the submission of regional haze SIPs.
The consent decree was also subject to
district court review before its entry.
Neither the commenters nor any other
party objected to the deadlines
established for EPA’s action on the
Wyoming regional haze SIP. The United
States District Court for Colorado found
the terms of the consent decree
reasonable.
The commenter’s argument that EPA
used these consent decree deadlines and
‘‘has committed to particular courses of
action on Wyoming’s SIP’’ with regard
to the Final Rule is without merit. The
consent decree did not limit or change
72 January 2, 2011 a Complaint was filed against
EPA in the federal district court for the District of
Colorado seeking declaratory and injunctive relief
under the Clean Air Act due to EPA’s failure to
meet regulatory and statutory deadlines for the
regional haze implementation plan. See WildEarth
Guardians v. Jackson, Case No. 11–cv–0001–CMA–
MEH (D. Colo.).
73 The EPA resolved this complaint by means of
a settlement agreement that was memorialized in a
Consent Decree that was entered by the Court on
June 6, 2011 (the ‘‘Consent Decree’’).
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EPA’s substantive rulemaking authority
or discretion in any way. Rather, the
consent decree specifically permitted
EPA to satisfy its obligations either by
approving the States’ regional haze SIPs
or by promulgating a FIP. EPA also
provided more than 70 days from the
date of publication in the Federal
Register for interested parties to submit
comments on the proposed rule, longer
than the 30-day public comment period
required by the Act. 42 U.S.C. 7607(h).
EPA obtained several extensions of the
consent decree deadline for Wyoming to
provide the Agency with adequate time
to conduct the rulemaking.74 For all
these reasons, neither the consent
decree nor the deadlines it imposed
rendered EPA’s Final Rule arbitrary,
capricious, or contrary to law.
Finally, EPA did not rely on
information that was not in the docket
for this rule. Therefore, contrary to
commenter’s assertions, all information
relied upon has been disclosed.
Comment: EPA quickly entered into a
settlement agreement to resolve the
special interest groups’ litigation, rather
than defend its actions and honor
Wyoming’s patience with EPA’s
inaction. In settling the litigation, EPA
agreed to take final action on
Wyoming’s SIP by April 15, 2012.
Consent Decree, WildEarth Guardians v.
Jackson, No. 1: 11–cv–00001–CMA–
MEH, at 4, ’1]6 (D. Colo. Separt 27,
2011) (WildEarth Guardians).
Recognizing that it still could not meet
its statutory obligation to act on
Wyoming’s SIP, EPA persuaded the
special interest groups to extend that
deadline thirty days to May 15, 2012.
Stip. to Extend Four Deadlines in
Consent Decree at 3, ∼ 6, WildEarth
Guardians, (D. Colo. Jan. 10, 2012).
On June 2, 2012, eighteen months
after Wyoming submitted its SIP, EPA
proposed to partially approve and
partially disapprove the SIP. 77 FR
33022. But, as a result of EPA’s
unlawfully delayed action, Wyoming’s
SIP became complete by operation of
law. See 42 U.S.C. 7410(k)(l)(B).
Accordingly, EPA cannot now propose
to disapprove Wyoming’s SIP on the
grounds that it lacks information. To do
otherwise is to render Section
110(k)(l)(B) meaningless.
Response: EPA disagrees with this
comment. First, the commenter offers no
74 EPA routinely notifies the states of these
extensions. For example, on December 11, 2012,
Region 8 Air Program Director Carl Daly called
Wyoming DEQ’s Steve Dietrich and his staff, to let
them know the Agency had submitted a motion to
the Court to re-propose the 309(g) rule. Mr. Daly
also contacted Mr. Dietrich on March 26, 2013 to
let the State know EPA was working on further
extensions, as the Agency needed additional time
to consult with our headquarters offices.
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grounds on which EPA could have
defended the cited litigation, which
involved mandatory statutory deadlines
under the Act.
Second, EPA disagrees with the
commenter’s interpretation of CAA
section 110(k)(l)(B). Under the CAA,
EPA’s SIP review is a two-step process.
See CAA Section 110(k). First, within
six months of a SIP submission, EPA
must make a threshold ‘‘completeness
determination’’ to determine whether
the SIP contains certain ‘‘minimum
criteria’’ designated by EPA as ‘‘the
information necessary to . . . determine
whether the plan submission complies
with the provisions of [the CAA].’’ See
id. Section 110(k)(1)(A), (B). These
minimum criteria are listed in
Appendix V to 40 CFR. Part 51 and
include a relatively short list of eight
‘‘Administrative Materials’’ and nine
‘‘Technical Support’’ requirements,
such as evidence that the state properly
adopted the SIP and technical
demonstrations that allow EPA to
evaluate compliance with the
substantive requirements of the CAA.
See 40 CFR. part 51, App. V. If EPA fails
to make the completeness determination
within six months, the SIP is deemed
complete by operation of law. See CAA
Section 110(k)(1)(C).
Importantly, however, a
determination of completeness, either
by EPA or by operation of law, does not
mean that the SIP has been approved as
compliant with the substantive
requirements of the CAA. Indeed,
Appendix V does not include any
substantive requirements, such as the
requirement that regional haze SIPs
include a five-factor BART analysis.
These requirements are included
elsewhere in the CAA, the Haze Rule,
and the BART Guidelines.
Instead, EPA evaluates SIPs for
compliance with the substantive
requirements in the second step of
EPA’s review, which EPA must
complete within one year after the SIP
is determined to be complete by EPA or
deemed complete by operation of law.
See CAA Section 110(k)(2), (3), & (l)
(providing a one-year deadline by which
EPA must determine whether the SIP
‘‘meets all of the applicable
requirements’’ or ‘‘interferes with any
applicable requirement’’ of the Act); see
also NRDC v. Browner, 57 F.3d 1122,
1126 (D.C. Cir. 1995) (‘‘Under the twostage procedure established in [section]
110(k), EPA first makes an essentially
ministerial finding of completeness, a
process taking at most six months. By
contrast, the plan approval process may
take up to twelve months due to the
more extensive technical analyses
necessary to ensure that the SIP meets
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the Act’s substantive requirements.’’
(emphasis added)). Accordingly, a
completeness determination in Step 1
does not deprive EPA of authority to
disapprove a SIP in Step 2 for failure to
comply with substantive requirements
of the CAA, the Haze Rule, and the
BART Guidelines. Instead, a
completeness determination merely
triggers EPA’s duty to evaluate the
substance of a SIP in the first instance
and either approve or disapprove the
SIP as necessary within one year. As
explained above, EPA has authority to
substantively review states’ five-factor
BART analyses in Step 2, and must
disapprove a SIP if its analysis fails to
comply with the requirements of the
CAA, the Haze Rule, or the BART
Guidelines. See Oklahoma, 723 F.3d at
1207–10. Thus, the comment is
incorrect in stating that EPA’s action
here renders section 110(k)(1)(B)
meaningless.
Moreover, courts have repeatedly
stated that EPA does not lose its
statutory authority to act under the CAA
for a failure to meet its statutory
deadline and that the proper remedy in
the case of delay is for a party to seek
an order to compel action. Oklahoma v.
EPA., 723 F.3d 1201, 1224 (10th Cir.
2013) (explaining that although the CAA
‘‘undoubtedly requires that the EPA
promulgate a FIP within two years, it
does not stand to reason that it loses its
ability to do so after this two-year
period expires’’); Montana Sulphur &
Chem. Co. v. EPA., 666 F.3d 1174, 1190
(9th Cir. 2012) cert. denied, 133 S. Ct.
409, (2012) (explaining that although
CAA has an ‘‘explicit deadline . . . it
does not follow that the agency loses
authority to act if it fails to meet that
deadline’’); Gen. Motors Corp. v. United
States, 496 U.S. 530, 541 (1990)
(holding EPA does not lose authority
under CAA because ‘‘other statutory
remedies are available when EPA delays
action on a SIP revision’’); see also
Brock v. Pierce Cnty., 476 U.S. 253, 260
(1986) (holding that when ‘‘there are
less drastic remedies available for
failure to meet a statutory deadline . . .
courts should not assume that Congress
intended the agency to lose its power to
act’’).
Comment: Two months after the
period for commenting on EPA’s 2012
proposal closed, EPA and the special
interest groups again modified the
consent decree to allow EPA additional
time to take action on Wyoming’s SIP.
See Stip. To Extend Deadline in Consent
Decree., WildEarth Guardians (D. Colo.
Oct. 3, 2012). Then, two months after
extending the deadline for action on
Wyoming’s SIP, EPA asked the court to
again extend EPA’s deadline, this time
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until September 27, 2013. Def.
Unopposed Mot. To Modify Two
Deadlines in Consent Decree, at 1,
WildEarth Guardians (Dec. 10, 2012).
As grounds for the request, EPA cited
the special interest groups’ comments,
which EPA asserted ‘‘necessitate[d] reproposal of the rule.’’ Id. at 3–4. The
court, in turn, granted EPA’s request.
Order To Modify Consent Decree,
WildEarth Guardians (Dec. 13, 2012).
Even after extending its deadline to take
action on Wyoming’s SIP three times,
EPA still needed more time. So, on
March 25, 2013, EPA and the special
interest groups again agreed to extend
EPA’s deadline for action on Wyoming’s
SIP. Stip. To Extend Deadlines in
Consent Decree, WildEarth Guardians
(March 25, 2013) (extending deadline
until Nov. 21, 2013). Seemingly as a
condition for obtaining the special
interests groups’ consent to the
extension, EPA ostensibly agreed to a
timetable for Wyoming sources to install
emission controls faster than what
Wyoming proposed. Compare id. at 2,
∼ 6 (‘‘EPA will propose to determine, for
each source subject to BART, the period
of time for BART compliance that is as
expeditious as practicable’’), with 78 FR
34778 (‘‘We propose that PacifiCorp
meet our proposed emission limit . . .
as expeditiously as practicable, but no
later than five years after EPA finalizes
action’’). Had Wyoming known when
EPA proposed the consent decree in
2011 that EPA would commit to a
particular course action on Wyoming’s
SIP, rather than just a date for taking
some unspecified action, Wyoming
would have sought to intervene in the
litigation.
Response: EPA disagrees that it
committed to any particular course of
action in the Consent Decree. The
Consent Decree only specified a
timetable for EPA to promulgate rules
consistent with its statutory obligations
under the CAA, but did not commit the
EPA to any particular course of action
not already required by law. In fact, the
Consent Decree specifically states:
‘‘Nothing in this Consent Decree shall
be construed to limit or modify any
discretion accorded EPA by the CAA or
by general principles of administrative
law in taking the actions which are the
subject of this Consent Decree,
including the discretion to alter, amend,
or revise any final actions contemplated
by this Consent Decree.’’
We disagree with the commenter’s
allegations that EPA agreed in the
Consent Decree to a timetable for
Wyoming sources to install BART
controls faster than what Wyoming
proposed in its SIP. Paragraph 6 of the
Stipulation To Extend Deadlines in
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5107
Consent Decree, WildEarth Guardians
(March 25, 2013) specifies that:
By May 23, 2013, EPA shall sign a notice
of re-proposed rulemaking in which it
proposes approval of a SIP, promulgation of
a FIP, partial approval of a SIP and
promulgation of a partial FIP, or approval of
a SIP or promulgation of a FIP in the
alternative, for the State of Wyoming, to meet
the regional haze implementation plan
requirements that were due by December 17,
2007, under 40 CFR 51.309(g). In its reproposal, EPA will propose to determine, for
each source subject to BART, the period of
time for BART compliance that is as
expeditious as practicable, as required by 42
U.S.C. Section 7491. (emphasis added).
Commenter neglects to include the
last phrase in this provision in its
comment—‘‘as required by 42 U.S.C.
Section 7491.’’ The Consent Decree
required EPA to meet that CAA
requirement.75 Therefore, the Consent
Decree mirrors and is consistent with
the CAA BART requirements.
Finally, we are acting consistently
with the Act and the RHR, as we discuss
in detail elsewhere throughout this final
action.
13. Monitoring, Recordkeeping and
Reporting
Comment: EPA proposed a FIP for all
monitoring, recordkeeping, and
reporting requirements related to BART
and reasonable progress sources for
which there is a SIP or FIP emissions
limit. EPA notes that the State’s
monitoring, recordkeeping, and
reporting language in their SIP includes
references to WAQSR chapters that EPA
has not approved as part of the SIP and
erroneously concludes that this means
Wyoming’s requirements are not
federally enforceable.
Wyoming does not concur with EPA’s
findings. The monitoring, recordkeeping
and reporting language in the State’s
regional haze SIP is taken directly from
air quality permits issued under the SIPapproved permitting provisions in
Chapter 6, Section 2 of the WAQSR, and
are therefore federally enforceable. See
40 CFR 52.2620(c)(1). When drafting the
monitoring, recordkeeping, and
reporting requirements, the State
incorporated the requirements of 40
CFR part 60 for trona facilities and for
EGUs. Specifically, 40 CFR part 60
subparts D and Da were incorporated
into the monitoring conditions for each
75 Additionally, the CAA defines the term ‘‘as
expeditiously as practicable’’ to mean ‘‘as
expeditiously as practicable but in no event later
than five years after the date of approval of a plan
revision under this section (or the date of
promulgation of such a plan revision in the case of
action by the Administrator under section 110(c)
[42 USCS Section 7410(c)] for purposes of this
section).’’ 42 U.S.C. 7491(g)(4).
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BART permit. In the case of EGUs, by
relying upon subpart D and Da, the State
is also incorporating the requirements of
40 CFR part 75, since the monitoring
provisions of subpart Da refer back to
the continuous emissions monitor
requirements under the Acid Rain
Program codified in 40 CFR part 75.
While Wyoming allows for data
substitution using the methodology
prescribed in 40 CFR part 75, this is
only applicable to annual emissions to
account for periods when the
continuous emissions monitor is down
and the emissions unit continues to
operate. Substituting data for these
operating periods is more conservative
than removing them altogether. EPA
asserts that there are numerous
clarifications and rewording needed;
however, these monitoring,
recordkeeping, and reporting
requirements are currently in effect for
PacifiCorp and Basin Electric units, and
the companies are able to demonstrate
compliance using them. Furthermore,
the recordkeeping and reporting
requirements contained in Chapter 5,
Section 2 of the WAQSR are modeled
after 40 CFR part 60, as these provisions
are delegated to the State by EPA. See
40 CFR 60.4(c). While WAQSR Chapter
5, Section 2 is not part of Wyoming’s
SIP, the requirements therein are
analogous to the federal New Source
Performance Standards requirements
and are made federally enforceable
through incorporation by a Chapter 6,
Section 2 BART permit and EPA’s
delegation to Wyoming.
Since these monitoring,
recordkeeping, and reporting
requirements are contained in federally
enforceable permits and the affected
companies are already able to
demonstrate compliance with the BART
emissions limits using them, Wyoming
concludes that it did include
appropriate and adequate monitoring,
recordkeeping, and reporting
requirements in the SIP.
Response: EPA disagrees with this
comment. As discussed above in this
section, EPA’s approach in this action is
entirely consistent with section
169A(b)(2) which, as we wrote when we
promulgated the BART Guidelines,
‘‘provides that EPA must require SIPs to
contain emission limits, schedules of
compliance, and other measures as may
be necessary to make reasonable
progress towards meeting the goal’’
(emphasis added). 70 FR 39120. The
regulations require that the states ‘‘must
submit an implementation plan
containing emission limitations
representing BART.’’ 40 CPR 51.308(e).
The Guidelines require that states ‘‘must
establish an enforceable emission limit
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for each subject emission unit at the
source and for each pollutant subject to
review that is emitted from the source.’’
70 FR 39172. CAA section 110(a)(2)(A)
also requires that SIPs shall ‘‘include
enforceable emission limitations . . . as
may be necessary or appropriate to meet
the applicable requirements of [the
Act].’’
Therefore, EPA disagrees that the use
of BART permits to implement the
monitoring, recordkeeping, and
reporting necessary to ensure
compliance with BART emission
limitations is adequate under the CAA.
In addition, in response to another
comment, we are removing the
requirements for annual emission limits
for BART and reasonable progress
sources. (See section IV.C.3 of this
rulemaking). Thus, the point raised by
the commenter pertaining to data
substitution no longer applies to our
final action.
B. Modeling
1. General Comments
Comment: One commenter stated that
EPA must re-evaluate its method for
assessing visibility impacts from
wildfires or states will never be able to
achieve natural background goals. The
commenter went on to say that EPA
should (1) eliminate the impacts from
fire from the annual contribution to the
deciview analysis or (2) properly
incorporate it into the natural
background equation to establish a glide
path states can achieve. The commenter
provided graphical data from the
Interagency Monitoring of Protected
Visual Environments (IMPROVE)
network to show the contributions to
light extinction from organic carbon,
elemental carbon, and nitrate.
Response: EPA disagrees that we must
re-evaluate our methods in this action.
However, EPA agrees that wildfires can
be an important source of visibility
impairment, especially in the western
states during the summer wildfire
season. EPA recognized that variability
in natural sources of visibility
impairment causes variability in natural
haze levels as described in its
‘‘Guidance for Estimating Natural
Visibility Conditions Under the
Regional Haze Rule.’’ 76 The preamble to
76 Guidance for Estimating Natural Visibility
Conditions Under the Regional Haze Rule,
Document No. EPA–R09–OAR–2012–0345–0003–
B9, U.S. Environmental Protection Agency,
September 2003. https://www.epa.gov/ttncaaa1/t1/
memoranda/rh_envcurhr_gd.pdf, page 1–1:
‘‘Natural visibility conditions represent the longterm degree of visibility that is estimated to exist
in a given mandatory Federal Class I area in the
absence of human-caused impairment. It is
recognized that natural visibility conditions are not
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the BART guidelines (70 FR 39124)
describes an approach used to measure
progress toward natural visibility in
Mandatory Class I areas that includes a
URP toward natural conditions for the
20 percent worst days and no
degradation of visibility on the 20
percent best days. The use of the 20
percent worst natural conditions days in
the calculation of the URP takes into
consideration visibility impairment
from wild fires, windblown dust and
other natural sources of haze. The
‘‘Guidance for Estimating Natural
Visibility’’ also discusses the use of the
20 percent best days and the 20 percent
worst days estimates of natural
visibility, provides for revisions to these
estimates as better data becomes
available, and discusses possible
approaches for refining natural
conditions estimates.77 The commenter
does not identify any way in which
EPA’s action was inconsistent with this
guidance or the RHR.
Comment: At the hearing, Governor
Mead and representatives of Wyoming,
as well as industry representatives,
argued that worsening haze has been
caused by wildfires.
Response: We acknowledge the
commenter’s points on wildfires,78 and
that they can be an important source of
visibility impairment, especially in the
western states during the summer
wildfire season. As discussed in more
detail above and in our proposed notice,
EPA recognizes that variability in
natural sources of visibility impairment
cause variability in natural haze levels
and provided approaches to address this
in the preamble to the BART guidelines
(70 FR 39124). However, while we
acknowledge that wildfires contribute to
regional haze, the BART CALPUFF
constant, but rather they vary with changing natural
processes (e.g., windblown dust, fire, volcanic
activity, biogenic emissions). Specific natural
events can lead to high short-term concentrations of
particulate matter and its precursors. However, for
the purpose of this guidance and implementation of
the regional haze program, natural visibility
conditions represents a long-term average condition
analogous to the 5-year average best- and worst-day
conditions that are tracked under the regional haze
program.’’
77 Ibid., pages 3–1 to 3–4.
78 78 FR at 34767 (‘‘Table 28 also shows that
Wyoming is not meeting the URP to meet natural
visibility conditions by 2064. In this case, 40 CFR
51.308(d)(1)(ii) requires the State to demonstrate,
based on the four factors in 51.308(d)(1)(i)(A), that
the RPGs established in this SIP are reasonable for
this planning period and that achieving the URP in
this planning period is not reasonable. In its
demonstration, the State cited many reasons why
meeting the URP was not reasonable, including the
following. First, emissions from natural sources
greatly affect the State’s ability to meet the 2018
URP. As discussed earlier, WEP data shows that
emissions of OC, EC, PM2.5, and PM10 come mainly
from natural or non-anthropogenic sources, such as
natural wildfire and windblown dust.’’)
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modeling has demonstrated that
Wyoming’s BART sources are also
significant contributors to regional haze.
Comment: Although the various
BART application analyses conducted
by Wyoming for PacifiCorp’s BART
units note that Wyoming conducted a
‘‘comprehensive visibility analysis
covering all three visibility impairing
pollutants,’’ the analyses also state:
‘‘While visibility impacts were
addressed in a cumulative analysis of all
three pollutants, Post-Control Scenario
B is directly comparable to Post-Control
Scenario A as the only difference is
directly attributable to the installation of
SCR. Subtracting the modeled values
from each other yield the incremental
visibility improvement from SCR.’’ In
other words, Wyoming clearly
considered—and made available to
EPA—the very specific NOX information
that EPA claims it ‘‘was not possible for
EPA, or any other party, to ascertain.’’
Simply claiming it ‘‘was not possible for
EPA’’ to ascertain results from available
information does not justify EPA in
rejecting Wyoming’s NOX BART
determinations. Wyoming had
considered SCR-specific visibility
information. EPA cannot use the alleged
lack of this information to justify
requiring SCR as BART.
Response: We disagree with all
aspects of this comment. Although a
state is not required by EPA’s
regulations to model the visibility
impacts from all possible control
alternatives if the state selects the most
stringent controls available as BART
that is not what happened here.
Wyoming rejected SNCR and SCR as
BART without adequately assessing the
visibility benefits of these control
strategies. Given the cost effectiveness
of these controls, the State’s failure to
consider visibility impacts was not
reasonable and was inconsistent with
the CAA and regulations. EPA was
compelled to perform additional
CALPUFF modeling for NOX BART
determinations to allow for
consideration of visibility impacts. For
example, while Wyoming took into
consideration the degree of visibility
improvement for other BART NOX
control options for the PacifiCorp EGUs,
such as SCR, the State did not do so for
SNCR. The visibility improvement for
SNCR was neither provided in the
State’s SIP nor made available to the
EPA. Wyoming did not assess the
visibility improvement of SNCR despite
having found it to be a technically
feasible control option, and having
considered a number of the other
statutory factors for SNCR, such as costs
of compliance and energy impacts.
Given that nothing in the State’s
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analysis suggested that SNCR was
inappropriate, Wyoming’s failure to
consider the visibility improvement of
SNCR is clearly in conflict with the
statutory requirements set forth in
section 169A(g)(2) of the CAA, which
require that states take into
consideration ‘‘the degree of
improvement in visibility which may
reasonably be anticipated to result from
the use of such technology.’’ Since
Wyoming did not do so, EPA conducted
additional CALPUFF modeling to fill
this gap in the State’s visibility analysis.
In addition, as stated in our 2012
proposed rule and in our 2013 reproposal, it was not possible for EPA, or
any other party, to ascertain the
visibility improvement from the NOX
control options as emission reductions
for multiple pollutants were modeled
together. That is, since the visibility
improvement for each of the State’s
control scenarios was due to the
combined emission reductions
associated with SO2, NOX, and PM
controls, it was not possible to isolate
what portion of the improvement was
attributable to the NOX controls alone.
For this reason, in the modeling
conducted by EPA, we held SO2 and PM
emission rates constant (reflecting the
‘‘committed controls’’ for those
pollutants identified by Wyoming), and
varied only the NOX emission rate. This
allowed us to isolate the degree of
visibility improvement attributable to
the NOX control option.
We do agree that Wyoming’s analysis
allows for the incremental comparison
between two post-control options (PostControl Scenario A and Post-Control
Scenario B). However, the BART
Guidelines require more than this,
stating that you should ‘‘[a]ssess the
visibility improvement based on the
modeled change in visibility impacts for
the pre-control and post-control
emission scenarios.’’ 79 That is, it is not
sufficient to assess only the incremental
visibility between control options, you
must also assess the visibility
improvement of each control option
relative to the pre-control scenario.
Therefore, Wyoming clearly did not
assess visibility improvement in a
manner consistent with that explicitly
prescribed by the BART Guidelines.
In summary, while States may have
some discretion in how to determine
visibility impacts, Wyoming did not
fulfill the basic statutory requirement to
consider the visibility improvement of
each of the NOX control options they
identified as technically feasible. They
also did not assess visibility
improvement in a manner consistent
79 40
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5109
with the approach prescribed by the
BART Guidelines. As a result, EPA
concluded it would be appropriate to
conduct additional CALPUFF modeling.
Comment: The egregiousness of EPA’s
actions becomes even more apparent
when comparing EPA’s conclusions
regarding cost and visibility impacts for
certain of PacifiCorp’s BART units
against the cost and visibility impact
conclusions reached by Wyoming for
the same units. Table 2 in our comments
provides a comparison between
Wyoming’s modeled delta deciview
improvements and EPA’s delta deciview
improvements based on the ‘‘new
information’’ EPA claims it has
developed. Recognizing EPA’s
conclusion that one deciview is barely
perceptible to the human eye and
considering the inaccuracies and
limitations of the model inputs and
versions of the visibility models being
used, there is no significant difference
between Wyoming’s results and EPA’s
results. Additionally, without any
‘‘bright line’’ test regarding the amount
of visibility improvement that justifies a
given control device, EPA cannot show
that these insignificant differences
would have any impact on the BART
determinations for PacifiCorp’s BART
units.
Response: With respect to the ‘‘bright
line’’ test, EPA’s task in conducting
modeling for developing our FIP is to
conduct modeling in accordance with
the CAA and RHR using our best
scientific and technical judgment. We
then consider the modeling results,
along with the other BART factors, in
making the BART determinations.
While it is permissible to establish a
‘‘bright line,’’ we have not done so.
Furthermore, as we discuss in detail in
section IV of this final notice and
elsewhere in response to comments, we
disagree with commenter’s assertions
that there are no significant differences
between Wyoming’s results and EPA’s
results. We have addressed the issue of
perceptibility elsewhere in our response
to comments.
Comment: We received comments
that by the year 2022, EPA’s plan and
Wyoming’s plan achieve essentially
identical results for visibility, and
therefore, the proposed FIP would have
no net visibility benefit over the SIP.
Response: We disagree. Our proposed
FIP, by merit of requiring more stringent
controls than those proposed in the SIP
for some sources shown to cause or
contribute to visibility impairment,
results in greater visibility benefit.
Although, based on our revised analyses
for visibility impacts and costs of
compliance and considering the five
BART factors, we have revised some of
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our proposed control determinations,
this assessment remains true for today’s
final rule. In particular, our final rule
results in greater visibility improvement
than the SIP for PacifiCorp Dave
Johnston Unit 3 and Wyodak and Basin
Electric Laramie River Units 1–3. The
improvement in visibility stemming
from the FIP, as compared to the SIP,
can easily be discerned by reviewing
relevant control options as found in
Tables 2 through 17 of section III.A of
this action.
Comment: On average, the 2000
baseline level for Class I areas in
Wyoming is 11 deciviews. The 2064
natural background goal is 6 deciviews.
IMPROVE data suggests that there is not
this amount of nitrate improvement to
be obtained. It appears EPA is trying to
achieve a greater reduction for nitrates
than is required at this time to reach the
2064 natural background goal. For
Bridger, the total amount of deciview
reduction for controls (6.08) exceeds the
entire deciview reduction (all
pollutants) from baseline to 2064. The
value (6.08 deciviews) is also 10 fold
higher than Wyoming’s contribution to
nitrate levels (0.62 deciviews—see Table
23 of EPA’s proposed rulemaking) at the
Class I area for the 2000–2004 baseline
year. This value was calculated by
multiplying 6.2% times the Class I
area’s 2000 baseline deciview value of
11.1. The same discussion is valid for
Yellowstone as well, where the modeled
nitrate reductions equal 2.27 deciviews
and Wyoming’s total reduction potential
is only 0.82 deciviews.
Response: EPA disagrees with this
comment. The commenter appears to be
referring to annual mean estimates of
visibility impairment at Class I areas,
and comparing these estimates with the
original CALPUFF modeled visibility
improvements in our 2012 proposal.
The values referred to in Table 23 of
EPA’s proposed rulemaking are mean
estimates for the 20% worst visibility
days. The BART Guidelines recommend
that visibility impairment be evaluated
for the 98th percentile contribution for
each BART source. It is likely that 98th
percentile visibility impacts will differ
significantly from annual mean impacts,
so it is not possible to directly compare
our modeled impacts on the 98th
percentile day to seasonal mean or the
mean of the worst 20% days. However,
we also note that in the revised final
modeling included in this action, the
CALPUFF modeled visibility
improvements are less than the values
cited above by the commenter from the
original proposal, and the commenter’s
comparisons are no longer relevant.
Comment: The measured visibility
impairment at IMPROVE stations offers
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a more certain and reliable
quantification of the actual cause of
visibility impairment than the
CALPUFF model approved by the EPA
for BART visibility assessments.
CALPUFF is an EPA-approved model
for long-range transport, as described in
the EPA’s ‘‘Guideline on Air Quality
Models’’ 40 CFR Part 51 Appendix W,
but only for the modeling of PSD
increments. The treatment of chemical
transformation, which is a crucial aspect
for any model that is used for visibility
assessments, is considered to be
inadequate within CALPUFF. In fact,
the lead modelers at the EPA’s Office of
Air Quality Planning and Standards
have initiated a formal regulatory
process to more fully evaluate (and very
possibly replace) CALPUFF as an EPApreferred model for long-range
transport.
Response: EPA disagrees that the use
of monitoring data from the IMPROVE
network would provide a more accurate
assessment of the predicted degree of
visibility from the use of controls at a
source than does CALPUFF. The
commenter has not explained how
monitoring data could be used to assess
the actual current contributions to
visibility impairment, and in any case,
models are needed to estimate the
potential future visibility impacts from
the use of a range of controls at a
specific source. In recommending the
use of CALPUFF for assessing source
specific visibility impacts, EPA
recognized that the model had certain
limitations but concluded that ‘‘[f]or
purposes of the regional haze rule’s
BART provisions . . . CALPUFF is
sufficiently reliable to inform the
decision-making process.’’ 80 EPA
accordingly appropriately used
CALPUFF in this action. We further
note that the requirements of 40 CFR
51.112 and 40 CFR part 51, Appendix
W, Guideline on Air Quality Models
(GAQM) and the BART Guidelines
which refers to GAQM as the authority
for using CALPUFF, provide the
framework for determining the
appropriate model platforms and
versions and inputs to be used. The use
of CALPUFF is subject to GAQM
requirements in section 3.0(b), 4, and
6.2.1(e) which includes an approved
modeling protocol to use the current 5.8
version.81
In promulgating the BART guidelines,
EPA addressed concerns with
CALPUFF’s treatment of chemical
80 70
FR at 39123.
of the ‘‘VISTAS’’ Version of the
CALPUFF Modeling System, EPA–454/R–08–007,
August 2008; also see CALPUFF Model Change
Bulletins B (MCB–B), MCB–C and MCB–D.
81 Assessment
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transformations by recommending that
states use the 98th percentile of
modeled visibility impacts,82 an
approach that EPA followed here, to
address the possibility that the model
could overestimate impacts. EPA’s
discussion of CALPUFF in this 2005
rulemaking addresses these issues at
length.83
EPA’s modeling in this action was
consistent with the BART Guidelines
and Appendix W. As explained in more
detail above, in recommending the use
of CALPUFF for assessing source
specific visibility impacts, EPA
recognized that the model had certain
limitations but concluded that ‘‘[f]or
purposes of the regional haze rule’s
BART provisions . . . CALPUFF is
sufficiently reliable to inform the
decision-making process.’’ 84 To the
extent that the comment takes issue
with the provisions in the BART
Guidelines for use of CALPUFF as
described above, the legal deadline for
challenging the use of CALPUFF has
passed. In addition we encourage the
commenter to provide input in the event
that EPA develops any new future
visibility guidelines and predictive
models.
With respect to the comment on the
IMPROVE data, we have addressed this
in the response to another comment.
Comment: Regional haze is affected
by global geologic, atmospheric and
anthropogenic sources. None of the
sources are controllable to the extent of
achieving ‘‘natural visibility conditions’’
at the targeted time frame. The
quantification of ‘‘natural visibility’’ at
any geographic point is irrational.
Natural visibility is a temporal quantity
and therefore any quantified value is
subjective and not scientific. Regional
haze is subject to global atmospheric
conditions which provide dilutive
action to the identified sources of haze
(anthropogenic or otherwise).
Atmospheric conditions are directly
related to the baseline eleven year solar
cycle. To have any form of validity, the
collection period would necessarily
encompass at least one full solar cycle,
arguably two full cycles. Furthermore,
the dilutive effects of atmospheric
conditions (and therefore, the
quantification of visibility) are directly
related to the known periodic oceanic
events commonly referred to as ‘‘el
˜
˜
Nino’’ and ‘‘la Nina’’. These events have
been monitored and quantified since
1950 and occurrences are subcategorized as weak, moderate and
strong. The periodicity of strong events
82 70
FR at 39121
FR at 39121–29124.
84 70 FR at 39123.
83 70
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˜
˜
for both ‘‘el Nino’’ and ‘‘la Nina’’ is
every 9–11 years. The last strong ‘‘el
˜
Nino’’ occurred in 1997. The last two
˜
strong ‘‘la Nina’’ events occurred in
2010 and 1999. The baseline data
collection for regional haze is ignorant
of these significant atmospheric events,
which makes the data collection period
irrelevant and therefore the ‘‘baseline
visibility’’ invalid.
Response: EPA disagrees with the
characterizations in this comment. EPA
recognizes that a variety of global scale,
natural emissions sources affect natural
visibility levels at Class I areas, and we
described methods used to assess
natural haze levels.85 We disagree that
it is necessary to model visibility
impairment for one or two full solar
cycles. The formation of fine particulate
matter, and subsequent impacts on
regional haze, depend on variations in
local meteorological conditions.
Variability in meteorological conditions
is primarily determined by seasonal
weather conditions, and the modeling
period of calendar years 2001–2003
used in our analysis includes
substantial variability in weather
conditions. While phenomena such as el
˜
˜
Nino and la Nina can affect the
frequency of extreme events, our
modeling analysis is based on the 98th
percentile visibility impacts and is
therefore designed to exclude extreme
˜
˜
events. El Nino and la Nina events may
also affect annual total precipitation,
temperature and other meteorological
parameters, however, the commenter
has not provided any evidence that the
98th percentile visibility impacts would
˜
differ significantly during an el Nino
˜
and la Nina year. We believe that it is
sufficient to model visibility
impairment for a 3 year period. In the
preamble to the BART Guidelines, we
discussed meteorological variability and
explained how use of the 98th
percentile would minimize the
likelihood that the highest modeled
visibility impacts would be caused by
unusual meteorological conditions. 70
FR 39121. As explained above, our use
of the 98th percentile is consistent with
the BART Guidelines and in
recommending the use of CALPUFF for
assessing source specific visibility
impacts, EPA recognized that the model
had certain limitations but concluded
that ‘‘[f]or purposes of the regional haze
rule’s BART provisions . . . CALPUFF
is sufficiently reliable to inform the
decision-making process.’’ 86 Thus to
85 ‘‘Guidance for Estimating Natural Visibility
Conditions under the Regional Haze Rule’’
Document No. EPA–R09–OAR–2012–0345–0003–
B9, U.S. Environmental Protection Agency,
September, 2003.
86 70 FR at 39123.
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the extent that the comment suggests
that the BART Guidelines should have
used a different percentile to account for
solar variability in solar cycles, the legal
deadline for challenging the use of
CALPUFF has passed. In addition we
encourage the commenter to provide
input in the event that EPA develops
any new future visibility guidelines and
predictive models.
2. EPA Modeling
a. Comments on EPA Modeling
Comment: Several commenters have
argued that EPA should have used
updated models and procedures for its
revised modeling. In addition, several
commenters have argued that the State’s
Protocol was overly conservative in its
treatment of background ammonia
concentrations, and that monitoring
data show that background ammonia
levels are significantly lower than the 2
ppb concentration specified in the
Protocol. Commenters in particular
directed EPA’s attention to ambient
monitoring data for ammonia and
particulate ammonium at a monitoring
site in Boulder in western Wyoming and
at several Class I areas. Ambient
monitoring at the Boulder site was
performed from 2006 to 2011 and these
data were recently published by Li et
al.,87 while the monitoring data at the
Class I areas for an 8 month period from
April 2011 to January 2012 and were
presented at a conference in 2012.88
Response: We agree with the
comments that we should perform new
modeling using updated model versions
and different background ammonia
concentrations. In this response we
explain why we originally used the
same modeling approach used by
Wyoming and why we have updated the
modeling for this action. In 2006, the
State adopted its ‘‘BART Air Modeling
Protocol’’ (Protocol) 89 that specified the
approach for using the CALPUFF
modeling system to evaluate BART
visibility impacts, and the State and
several BART sources performed
modeling studies that were consistent
with that protocol. For our original
proposal in 2012, EPA performed
87 Li, Y., Schwandner, F.M., Sewell, H.J.,
Zivkovich, A., Tigges, M., Raja, S., Holcomb, S.,
Molenar, J.V., Sherman, L., Archuleta, C., Lee, T.,
Collett Jr., J.L., Observations of ammonia, nitric
acid, and fine particles in a rural gas production
region, Atmospheric Environment (2013), doi:
10.1016/j.atmosenv.2013.10.007.
88 Chen et al., A Pilot Monitoring Study of
Atmospheric NHx at Selected IMPROVE sites
AWMA Aerosol and Atmospheric Optics, Visibility
& Air Pollution Conference, September 24–28, 2012,
Whitefish, MT.
89 Wyoming’s ‘‘BART Air Modeling Protocol’’
(Protocol) is included in the docket in the State’s
Technical Support Document.
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5111
additional modeling using the State’s
Protocol to evaluate a limited number of
emissions scenarios that the State had
not evaluated in its modeling. EPA
recognized that there had been updates
to CALPUFF modeling guidance and
model versions after 2006 when the
State adopted the Protocol, however, in
our original proposal in 2012, which
included a limited, gap-filling analysis,
we proposed that it was preferable to
maintain consistency with the modeling
approach that the State had adopted in
its Protocol. In our re-proposal on June
10, 2013, EPA recognized that some of
the options used from the State’s
Protocol were inconsistent with BART
Guidelines, such as the approach for
determining baseline emissions. As a
result, for the re-proposal EPA
performed new modeling using updated
emissions data for the baseline period
and for all emissions control
technologies, however, EPA continued
to use the State’s Protocol for EPA’s reproposed modeling analysis.
After evaluating comments on the reproposal, EPA determined that it was
necessary to remodel all of the baseline
and control technology scenarios using
different background ammonia
concentrations for the BART sources
that we reconsidered for this action,
including Naughton, Jim Bridger,
Laramie River, Dave Johnston and
Wyodak. Because this approach
represents a significant change from
State’s original Protocol, we believed
that it was appropriate to develop a new
modeling protocol that also adopts the
current model version approved for
regulatory use, CALPUFF version 5.8,
and current regulatory default options.
In making this decision, we considered
the merits of continuing to use the
State’s original protocol versus the
benefits of using the updated CALPUFF
model that became available after the
State’s Protocol was adopted, and
different background ammonia
concentrations based in part on data
that have also become available since
then, and we concluded that it was
necessary to adopt an updated
Protocol 90 to respond fully to a number
of issues raised by various commenters.
The new EPA Protocol for modeling of
Wyoming BART uses the same
CALPUFF model version 5.8 as did the
protocol that we previously adopted for
modeling BART sources visibility
impacts in Montana.91
90 Air Quality Modeling Protocol: Wyoming
Regional Haze Federal Implementation Plan, U.S.
EPA, January, 2014.
91 Modeling Protocol: Montana Regional Haze
Federal Implementation Plan (FIP) Support,
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EPA evaluated the comments and the
ambient ammonia monitoring data
submitted by commenters. EPA
understands that there is no single
accepted method for estimating the
background concentration of ammonia,
and that any method will have
advantages and disadvantages. The lack
of consensus on a method was a factor
in EPA’s decision to set aside the 2 ppb
concentration value specified in the
State’s Protocol and instead to rely in
part on the default values in Interagency
Workgroup on Air Quality Modeling
(IWAQM) Phase 2 report 92 and in part
on monitoring data. Specifically, for
BART sources in western Wyoming we
performed two modeling runs, one
relying on an IWAQM default value and
the other relying only on monitoring
data. As presented below, EPA’s two
sets of modeling results for this BART
source support our final BART
determinations, as they both show
similar visibility benefits. As explained
below, we relied only on an IWAQM
default value for BART sources in
eastern Wyoming.
The 1998 IWAQM report is the only
guidance available for choosing
ammonia background concentrations.
The IWAQM Phase 2 report relied on a
1992 review of ambient monitoring data
for ammonia by Langford et al.93 and
explains that: ‘‘. . . the formation of
particulate nitrate is dependent on the
ambient concentration of ammonia,
which preferentially reacts with sulfate.
The ambient ammonia concentration is
an input to the model. Accurate
specification of this parameter is critical
to the accurate estimation of particulate
nitrate concentrations. Based on a
review of available data, Langford et al.
suggest that typical (within a factor of 2)
background values of ammonia are: 10
ppb for grasslands, 0.5 ppb for forest,
and 1 ppb for arid lands at 20 degrees
Celsius. Langford et al. (1992) provide
strong evidence that background levels
of ammonia show strong dependence
with ambient temperature (variations of
a factor of 3 or 4) and a strong
dependence on the soil pH. However,
given all the uncertainties in ammonia
data, IWAQM recommends use of the
background levels provided above,
prepared for EPA Region 8 by Alpine Geophysics,
LLC, November 21, 2011.
92 Interagency Workgroup On Air Quality
Modeling (IWAQM) Phase 2 Summary Report And
Recommendations For Modeling Long Range
Transport Impacts (EPA–454/R–98–019), EPA
OAQPS, December 1998, https://www.epa.gov/
scram001/7thconf/calpuff/phase2.pdf.
93 Langford, A.O., F.C. Fehsenfeld, J.
Zachariassen, and D.S. Schimel (1992), Gaseous
ammonia fluxes and background concentrations in
terrestrial ecosystems of the United States, Global
Biogeochemical Cycles, 6, 459–483.
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unless specific data are available for the
modeling domain that would discredit
the values cited. It should be noted,
however, that in areas where there are
high ambient levels of sulfate, values
such as 10 ppb might overestimate the
formation of particulate nitrate from a
given source, for these polluted
conditions. Furthermore, areas in the
vicinity of strong point sources of
ammonia, such as feed lots or other
agricultural areas may experience
locally high levels of background
ammonia.’’ 94
The IWAQM Phase 2 report also states
that ‘‘[i]n a refined analysis, ‘‘the
background concentrations of ozone and
ammonia are allowed to vary in time
and space.’’ 95 In summary, given
numerous uncertainties in ammonia
data, the IWAQM Phase 2 report
recommends use of the background
values it provides for different land use
categories, unless specific data is
available in the modeling domain as a
more accurate substitute for its
recommended default values, and
allows for the consideration of
background ammonia concentrations
that vary seasonally or spatially.
EPA has reviewed monitoring data for
ammonia and ammonium that have
been collected at one site in western
Wyoming since 2006.96 We have
determined that the monitoring data
from this site are the most
representative monitoring data available
for characterizing ammonia and
ammonium background levels in the
modeling domains used for western
Wyoming as explained in detail below.
Based on this analysis, EPA has
concluded that the constant 2 ppb
background concentration used by the
State is substantially higher than the
observed combined ammonia and
particulate ammonium concentrations at
this monitoring site in western
Wyoming, especially during the winter
season when the observed sum of
ammonia and particulate ammonium
concentration were typically much
lower than 2 ppb.97 Therefore, for two
BART sources in western Wyoming
(PacifiCorp’s Naughton and Jim Bridger)
in one of our modeling runs we
94 Interagency Workgroup On Air Quality
Modeling (IWAQM) Phase 2 Summary Report And
Recommendations For Modeling Long Range
Transport Impacts, EPA–454/R–98–019, (December
1998) pages 14–15.
95 IWAQM, Ibid., page 6.
96 Li, Y., Schwandner, F.M., Sewell, H.J.,
Zivkovich, A., Tigges, M., Raja, S., Holcomb, S.,
Molenar, J.V., Sherman, L., Archuleta, C., Lee, T.,
Collett Jr., J.L., Observations of ammonia, nitric
acid, and fine particles in a rural gas production
region, Atmospheric Environment (2013), doi:
10.1016/j.atmosenv.2013.10.007.
97 Li et al. U.S. EPA, December, 2013.
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modeled using monthly varying
ammonia background concentrations
based on the combined observed
concentration of ammonia and
particulate ammonium at this
monitoring site in western Wyoming, as
described in the EPA Protocol.98 In a
second modeling run for these two
BART sources, we modeled using the
default IWAQM ammonia concentration
of 0.5 ppb for forested areas. Although
western Wyoming includes a mixture of
arid grasslands and forested areas, we
used the IWAQM default value of 0.5
ppb for forested areas because the Class
I areas in the modeling domain are
primarily forested, and because the
monitoring data more nearly matched
the IWAQM recommendation for forests
than the default for the other land types.
When Wyoming adopted its Protocol
in 2006, the State explained that: ‘‘A
constant background ammonia
concentration of 2.0 ppb is specified.
This value is based upon monitoring
data from nearby states and IWAQM
guidance. Experience suggests that 2.0
ppb is conservative in that it is unlikely
to significantly limit nitrate formation in
the model computations.’’ 99
The Wyoming Protocol specified a
constant 2 ppb background ammonia
concentration, but the Protocol
(addressing source owners performing
their own BART analyses) states that:
‘‘[i]f you believe that ammonia limiting
is appropriate for a specific BART
analysis, justification should be
discussed with the Division prior to its
use.’’ 100 The Wyoming Protocol in the
text quoted here refers to a method for
correcting CALPUFF for ammonia
limiting conditions, which indicates
that the State recognized the possibility
that its protocol could be overly
conservative in its treatment of
ammonia. Therefore, we believe it is
appropriate and consistent with the
IWAQM Phase 2 report and the
intention of the State’s Protocol to
model a BART source in western
Wyoming using both the newly
available monitoring data, and the
default concentration recommended in
the IWAQM Phase 2 report, to represent
background ammonia concentrations
more accurately than would be the case
if we retained the 2 ppb value specified
in the State Protocol.
We describe here in more detail the
ambient monitoring data from the site in
western Wyoming and our use of those
98 Air Quality Modeling Protocol: Wyoming
Regional Haze Federal Implementation Plan.
99 Wyoming Protocol, p. 12.
100 Wyoming Protocol, p. 15.
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data. Li et al (2013) 101 report on an
analysis of ambient monitoring data
conducted from 2006 to 2011 at the
Pinedale site in western Wyoming in an
area with significant oil and gas
production. The monitoring site
included measurements of gaseous
ammonia (NH3) and particulate
ammonium (NH4) and a complete set of
acidic species including gaseous nitric
acid and particulate nitrate and sulfate.
The complete set of measurements
makes it possible to determine the total
ammonia and ammonium concentration
(NHX=NH3+NH4) and to determine if
ammonium nitrate formation is limited
by the availability of excess NH3. Li et
al found significant seasonal variability
in NH3 and NH4 concentrations at the
site and concluded that excess nitric
acid was present in winter, while NH3
concentrations were close to zero in
winter, indicating that formation of
ammonium nitrate was limited by the
availability of ammonia at this site in
winter.102 Because ammonia at this
monitoring site may have been affected
by nearby sources of sulfuric acid and
nitric acid, which would deplete the
gaseous ammonia concentration locally,
we used the combined gaseous and
particulate measurement of NHX to
estimate monthly average background
ammonia concentrations, with a low
concentration in January of 0.36 ppb
and a peak concentration in 1.12 ppb in
August.103 The monitor is located in an
area that includes nearby sources of
ammonia emissions from livestock and
other anthropogenic sources, including
a nearby area of oil and gas production
activity, which could result in locally
elevated ammonia compared to the area
more immediate to the BART source
and to the nearest Class I areas.
Moreover, some of the particulate
ammonium observed at the site was
irreversibly bound with sulfate and may
have had a non-local origin due to long
range transport of ammonium sulfate.
These factors mean that this estimate of
local background may tend to
overestimate the regional background
ammonia concentration and thus also
overestimate the visibility benefit due to
NOX reductions at sources. There may
be other unknown factors also working
in the same direction or in the other
101 Li, Y., Schwandner, F.M., Sewell, H.J.,
Zivkovich, A., Tigges, M., Raja, S., Holcomb, S.,
Molenar, J.V., Sherman, L., Archuleta, C., Lee, T.,
Collett Jr., J.L., Observations of ammonia, nitric
acid, and fine particles in a rural gas production
region, Atmospheric Environment (2013), doi:
10.1016/j.atmosenv.2013.10.007.
102 Li et al., Ibid.
103 Air Quality Modeling Protocol: Wyoming
Regional Haze Federal Implementation Plan,U.S.
EPA, December, 2013, page 18, Table 7.
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direction. For example, monitoring
methods for ammonia and quality
systems for characterizing monitoring
accuracy have not been standardized to
the extent that methods for other
ambient compounds have been,
resulting in uncertainty as to whether
there is bias in the measurements.
As discussed above, we also modeled
the PacifiCorp Naughton and Jim
Bridger BART sources in western
Wyoming using a constant background
ammonia concentration of 0.5 ppb,
which is the IWAQM Phase 2 report
default recommendation for forested
areas. Model results using either
approach to determine an ammonia
background concentration support our
final BART determinations, as they both
show similar visibility benefits.
We also remodeled the BART sources
in eastern Wyoming including Wyodak,
Dave Johnston and Laramie River. The
Class I areas most impacted by these
BART sources are Badlands and Wind
Cave National Parks in western South
Dakota. The closest long-term ammonia
monitoring site to these Class I areas is
at site at Beulah, North Dakota operated
by the State of North Dakota. This site
is about 280 miles from Badlands
National Park and about 300 miles away
from Wind Cave NP. The area around
Beaulah site includes a mix of
agricultural lands and grassland.
Measured monthly average gaseous
ammonia concentrations at the Beulah
site in central North Dakota vary from
about 1 to 2 ppb throughout the year,
with the lowest values in fall and
winter.104 Additionally, combined
ammonia and particulate ammonium
measurements have been reported at
Wind Cave National Park for an 8 month
period by Chen et al.105 This study
measured NHX daily average
concentrations in the range of about
0.05 to 4 ppb, with an annual average
concentration of 0.75 ppb. We
considered these monitoring data
sufficient to put into serious doubt the
2 ppb concentration specified in the
State’s Protocol, but insufficient to
support either a single or an alternative
modeling run based on monitoring data.
Therefore, we chose to rely on the
IWAQM Phase 2 report for a single set
of modeling runs for the BART sources
in eastern Wyoming. The area around
104 Protocol for BART-Related Visibility
Impairment Modeling Analyses in North Dakota,
November, 2005, North Dakota Department of
Health, Division of Air Quality, 1200 Missouri
Avenue, Bismarck, ND 58506. Page 33.
105 Chen et al., A Pilot Monitoring Study of
Atmospheric NHX at Selected IMPROVE sites
AWMA Aerosol and Atmospheric Optics, Visibility
& Air Pollution Conference, September 24–28, 2012,
Whitefish, MT.
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5113
Wind Cave National Park includes
forested areas, including Black Hills
National Forest, while the area around
Badlands National Park includes a mix
of arid and grass lands. While there is
uncertainty in the appropriate
background ammonia level in this
region, we used the IWAQM Phase 2
report recommended value of 1 ppb for
arid lands because it falls within the
range of the limited monitoring data
available in nearby regions and because
it is represents an intermediate level for
the different land use types within the
region.
For both the eastern and western
Wyoming modeling domains and runs,
we corrected for ammonia limiting
conditions. The correction for ammonia
limiting conditions is a post-processing
step in POSTUTIL, one component of
the CALPUFF modeling system.
Because CALPUFF simulates each
BART unit individually, the background
ammonia concentration is assumed by
the model to be fully available to react
with emissions from each unit. In
reality, the total emissions from the
combined units compete for the
available ammonia. Also, because
CALPUFF simulates multiple parcels of
air originating at each unit, there is the
possibility that different parcels can
overlap at a Class I area. The ammonia
limiting correction in POSTUTIL is
designed to repartition the available
ammonia to react with emissions from
all of the units and overlapping air
parcels, thereby avoiding double
counting of the background ammonia.
We used the same ammonia limiting
correction in our modeling for Montana
BART 106 sources, and this is a standard
configuration in the CALPUFF modeling
system.
In summary, we concluded that it was
more reasonable to model visibility
impacts in western Wyoming using both
the default IWAQM Phase 2 report
recommendation for forested areas and
using a seasonally varying NH3
concentration in western Wyoming that
was based on long term monitoring of
NH3 and NH4 from one site, than to use
the 2 ppb concentration specified in the
State’s Protocol. We found that the
visibility impacts predicted for the
various control levels at the PacifiCorp
Naughton and Jim Bridger BART
sources were very similar with these
two approaches and that either set of
results supports the same BART
determination for these sources.
Therefore, we did not have to make a
106 Modeling Protocol: Montana Regional Haze
Federal Implementation Plan (FIP) Support,
prepared for EPA Region 8 by Alpine Geophysics,
LLC, November 21, 2011.
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determination that one approach was
superior to the other, and we have not
done so. We also determined that it was
appropriate to use the default IWAQM
Phase 2 report recommendation of 1 ppb
for eastern Wyoming.
Comment: A commenter believes that
the improvements from the addition of
SCR technology are based on highly
conservative models which overestimate
the deciview reduction as compared to
actual monitored data collected at the
IMPROVE stations. Subsequently, the
improvement in visibility provided by
SCR is not supported by the escalated
costs of $600 million above the cost to
install Wyoming’s proposed control
technologies.
Response: EPA disagrees with this
comment to the extent that it takes issue
with EPA’s modeling. As discussed in
response to other commenters, EPA
recognized that the State’s original
modeling protocol specified a fixed
value of 2 ppb for background ammonia.
EPA has performed new modeling using
lower background concentrations and
using a correction for ammonia limiting
conditions when modeling multiple
units from a single BART source.
EPA also used the most current
regulatory approved versions of the
models in the updated modeling. EPA
has recognized that the CALPUFF
model can be conservative in estimating
visibility impairment, and therefore,
EPA has used the 98th percentile model
results instead of the maximum
modeled visibility impairment to
address the possibility of model
overpredictions. In recommending the
use of CALPUFF for assessing source
specific visibility impacts, EPA
recognized that the model had certain
limitations but concluded that ‘‘[f]or
purposes of the RHR’s BART provisions,
CALPUFF is sufficiently reliable to
inform the decision making process,
e.g., see 77 FR 39123.107 As discussed
107 77 FR 39123: ‘‘Because of the scale of the
predicted impacts from these sources, CALPUFF is
an appropriate or a reasonable application to
determine whether such a facility can reasonably be
anticipated to cause or contribute to any
impairment of visibility. In other words, to find that
a source with a predicted maximum impact greater
than 2 or 3 deciviews meets the contribution
threshold adopted by the States does not require the
degree of certainty in the results of the model that
might be required for other regulatory purposes. In
the unlikely case that a State were to find that a 750
MW power plant’s predicted contribution to
visibility impairment is within a very narrow range
between exemption from or being subject to BART,
the State can work with EPA and the FLM to
evaluate the CALPUFF results in combination with
information derived from other appropriate
techniques for estimating visibility impacts to
inform the BART applicability determination.
Similarly for other types of BART eligible sources,
States can work with the EPA and FLM to
determine appropriate methods for assessing a
single source’s impacts on visibility.’’
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above, to the extent that the comment
takes issue with the use of the 98th
percentile, the legal deadline for
challenging the use of CALPUFF has
passed, but we encourage the
commenter to provide input in the event
that EPA develops any new future
visibility guidelines and predictive
models.
Comment: The commenter states that
EPA made five errors in its visibility
modeling, including (1) given the
general inaccuracy in CALPUFF unitspecific modeling, not allowing
Wyoming the deference accorded it
under the CAA; (2) relying upon an
outdated CALPUFF method of visibility
modeling, contrary to EPA precedent;
(3) violating the applicable modeling
guidance, Appendix W, by not using the
‘‘best’’ science; (4) violating the Data
Quality Act by not using the ‘‘best’’
science; and (5) failing to recognize the
gross overestimations and internal
inconsistencies in EPA’s modeling
approach.
Response: EPA disagrees with this
comment. In response to item (1): In
promulgating the BART guidelines we
made the decision in the final BART
Guideline to recommend that the model
be used to estimate the 98th percentile
visibility impairment rather than the
highest daily impact value as proposed.
We made the decision because ‘‘there
are other features of our recommended
modeling approach that are likely to
overstate the actual visibility effects of
an individual source. Most important,
the simplified chemistry in the model
tends to magnify the actual visibility
effects of that source. Because of these
features and the uncertainties associated
with the model, we believe it is
appropriate to use the 98th percentile, a
more robust approach that does not give
undue weight to the extreme tail of the
distribution.’’ 77 FR 39121. In regard to
deference to the state, as discussed in
more detail elsewhere in this document,
Congress crafted the CAA to provide for
states to take the lead for implementing
plans, but balanced that decision by
requiring EPA to approve the plans or
prescribe a federal plan should the state
plan be inadequate to meet CAA and
regulatory requirements. Our action
today is consistent with the statute and
regulations. In response to item (2): We
initially relied on the State’s modeling
Protocol, adopted in 2006, that specified
model versions available at that time,
but that have since been updated. In our
original proposal we performed limited
gap filling modeling that was consistent
with the State’s Protocol and that used
the same model versions as the State. In
this final action, as presented in more
detail in the Protocol in the docket, due
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to a number of other changes in the
protocol, we also updated the protocol
to use the current regulatory version of
the CALPUFF modeling system. In
response to items (3) and (4): In
recommending the use of CALPUFF for
assessing source specific visibility
impacts, EPA recognized that the model
had certain limitations but concluded
that ‘‘[f]or purposes of the regional haze
rule’s BART provisions . . . CALPUFF
is sufficiently reliable to inform the
decision-making process.’’ 108 EPA
accordingly appropriately used
CALPUFF in this action. EPA
recognized that there were uncertainties
in the science of the CALPUFF
modeling system, and therefore used the
less conservative 98th percentile value
to model results to address the
possibility that the model was overly
conservative. We address concerns
about the Data Quality Act (also referred
to as the Information Quality Act),
elsewhere in this document. In response
to item (5): EPA recognized that the
State’s original Protocol was
inconsistent with the IWAQM report
and monitoring data because of the use
of a constant 2 ppb ammonia
concentration, and our modeling in this
action relied on ambient monitoring
data and the default values consistent
with IWAQM Phase 2 report, to specify
two alternatives for more realistic
background ammonia concentrations in
western Wyoming. We also reduced the
background ammonia concentration
from 2 to 1 ppb in eastern Wyoming, as
discussed previously. A seasonal
ammonia concentration was not
adopted due to the lack of high quality
monitoring data in eastern Wyoming;
however, as discussed previously, the 1
ppb background estimate is consistent
with IWAQM Phase 2 report. As
discussed elsewhere, we also used the
ammonia limiting correction for
modeling multiple units from a single
BART source to address concerns with
the model being overly conservative.
Comment: Contrary to its own
guidance, EPA failed to use the most
realistic model. 40 CFR part 51,
Appendix W, EPA’s modeling guidance,
demands that the ‘‘best’’ model should
always be used. EPA failed to use the
‘‘best’’ model in Wyoming, which is
CALPUFF 6.4. Therefore, EPA failed to
follow Appendix W’s requirements.
Response: We disagree with this
comment. As explained above, EPA
followed the RHR. Specifically, in
recommending the use of CALPUFF for
assessing source specific visibility
impacts, EPA recognized that the model
had certain limitations but concluded
108 70
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that ‘‘[f]or purposes of the regional haze
rule’s BART provisions . . . CALPUFF
is sufficiently reliable to inform the
decision-making process.’’ 109 EPA
accordingly appropriately used
CALPUFF in this action. The use of
CALPUFF is subject to GAQM
requirements in section 3.0(b), 4, and
6.2.1(e) which includes an approved
protocol to use the current 5.8 version,
which is the version we used for EPA’s
final modeling analysis. We did not use
CALPUFF Version 6.4 because this
version of the model has not been
approved by EPA for regulatory use.
We made the decision in the final
BART Guidelines to use less than the
highest daily impact value for
assessment of visibility impacts. We
made this decision in response to
comments we received expressing
concern that the chemistry modules in
the CALPUFF model are less advanced
and that use of the 1st High was
conservative and the knowledge that
CALPUFF’s simplified chemistry could
lead to model overpredictions and thus
be conservative. We decided in the
BART Guideline to use the 98 percentile
for CALPUFF based modeling results.
We also received comments opposed to
using the day with the worst
meteorology, but the primary reason we
changed to using a less stringent metric
than the day with the highest visibility
impact was because of concerns about
overestimations in CALPUFF’s
simplified chemistry. As a result, we
determined that it was appropriate to
use the 98th percentile or 8th High
value when modeling all days of the
year instead of the 1st High value, also
described as the Highest Daily impact
level for each year modeled: ‘‘Most
important, the simplified chemistry in
the model tends to magnify the actual
visibility effects of that source. Because
of these features and the uncertainty
associated with the model, we believe it
is appropriate to use the 98th
percentile—a more robust approach that
does not give undue weight to the
extreme tail of the distribution.’’ 110
Comment: EPA’s modeling for its
regional haze FIP action was inadequate
and incomplete. (EPA failed to re-run
WRAP regional modeling due to ‘‘time
and resource constraints’’). Therefore,
EPA’s regional haze FIP action violates
the ‘‘Guideline on Air Quality Models,’’
40 CFR part 51 Appendix W, the
Information Quality Act and the
implementing guidelines issued,
respectively, by the U.S. Office of
Management and Budget (OMB) and the
EPA which require information
disseminated by EPA to be accurate,
109 70
FR at 39123.
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complete, reliable and unbiased. The
Information Quality Act and EPA’s
‘‘Information Quality Guidelines’’ place
a heightened standard on ‘‘influential’’
information, including scientific
information regarding health, safety, or
environmental risk assessments. EPA’s
inaccurate and incomplete visibility
modeling is by definition ‘‘influential,’’
because EPA could reasonably
determine that dissemination of the
information will have or does have a
clear and substantial impact on
important public policies or important
private sector decisions, such as the
BART NOX determinations in EPA’s
regional haze FIP.
Therefore, this ‘‘influential’’
information must be based on best
available science and data and
supporting studies must be conducted
in accordance with sound objective
scientific practices and methods. EPA’s
Guidelines implementing the
Information Quality Act expressly
contemplate the correction of
information disseminated by EPA that
falls short of the ‘‘basic standard of
quality, including objectivity, utility,
and integrity,’’ established by either
EPA’s own Guidelines or those issued
by OMB.
The commenter seeks correction to a
number of errors and omissions in
EPA’s regional haze FIP with regard to
CALPUFF modeling and EPA’s failure
to re-run the WRAP model. The
commenter requests that EPA withdraw
its regional haze FIP until these issues
are resolved.
Response: As EPA explained in our
Information Quality Guidelines, we
believe ‘‘that the thorough consideration
provided by the public comment
process serves the purposes of the
Guidelines, provides an opportunity for
correction of any information that does
not comply with the Guidelines, and
does not duplicate or interfere with the
orderly conduct of the action.’’ 111
Therefore, we are responding to the
modeling comments and related
comments regarding EPA’s Guidelines
and the Information Quality Act in this
document.
WRAP performed regional
photochemical modeling using both the
Community Multi-Scale Air Quality
modeling system (CMAQ) and
Comprehensive Air Quality Model
(CAMx) air quality models to evaluate
progress toward attaining visibility goals
111 Guidelines for Ensuring and Maximizing the
Quality, Objectivity, Utility, and Integrity of
Information Disseminated by the Environmental
Protection Agency, EPA/260R–02–008 October
2002, U.S. Environmental Protection Agency Office
of Environmental Information (2810) 1200
Pennsylvania Avenue NW., Washington, DC 20460.
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5115
using all projected emission changes
from all source categories throughout
the United States. WRAP did not
perform regional photochemical
modeling to evaluate the visibility
impacts of individual BART sources.
While WRAP did make assumptions
regarding the level of emissions control
that would be adopted by BART sources
as part of its analyses, no state or EPA
region has re-run the WRAP’s regional
photochemical models to assess
individual BART source contributions
to visibility impairment. Instead, the
BART sources, the states, and EPA have
used the CALPUFF model to evaluate
contributions to visibility impairment
from individual BART sources. This
approach is consistent with the BART
Guidelines that recommend that the
CALPUFF model should be used to
evaluate visibility impairment from
individual BART sources. Additionally,
while EPA supported development of
WRAP CMAQ modeling in order to
assist states in developing their RPGs
and determining the cumulative benefit
`
of an overall control strategy vis-a-vis
the URP on the 20% worst days, our use
of CALPUFF for evaluating visibility
improvement from a single BART
source is consistent with the BART
Guidelines and also consistent with
modeling performed by other states and
EPA regional offices for individual
BART sources.
We have responded to comments
related to errors and omissions in the
CALPUFF modeling in separate
response to comments.
Comment: The commenter states that
the revised EPA modeling, which used
new information on emissions rates, did
not significantly change the results
identified in Wyoming’s BART analyses.
The commenter also states that there are
small differences between EPA’s and
Wyoming’s analyses which do not
justify EPA rejecting Wyoming’s BART
determinations.
Response: We disagree that in all
cases there are only small differences in
EPA revised modeling and the State’s
modeling. Importantly, as described
elsewhere in this document and in the
docket for this action, EPA revised and
corrected various inputs to the BART
factors so that the analyses are
consistent with the RHR and statutory
requirements. While the difference at
the most impacted Class I area from
individual sources or units is some
cases can be characterized as small, the
cumulative differences from many small
improvements can be significant.
Whether such differences are significant
will depend on the overall
consideration of the BART factors.
Because of the flaws in Wyoming’s
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visibility and cost analyses for many of
its BART sources, EPA could not be
confident that Wyoming’s BART
determinations were reasonable without
undertaking an appropriate analysis of
the statutory factors.
Comment: The commenter states that
Wyoming provided the required
modeled visibility improvement
information for SCR, and quotes from
the State’s analysis: ‘‘Post-Control
Scenario B is directly comparable to
Post-Control Scenario A as the only
difference is directly attributable to the
installation of SCR.’’ The commenter
then concludes EPA did not lack the
required information to evaluate
visibility improvements.
Response: We have addressed this
comment in a previous response, citing
the requirement in the BART Guidelines
that visibility must be assessed relative
to the pre-control scenario (and not just
incremental to other control scenarios).
Moreover, there remain deficiencies, as
presented elsewhere in this document
and docket, with the State’s BART
modeling analyses that justify our
rejection of the State’s BART
determinations for PacifiCorp. Most
notably, as discussed in separate
responses, the State did not assess the
visibility improvement of SNCR as
required by the CAA and BART
Guidelines.
Comment: An older version of the
CALPUFF modeling suite was used by
EPA (CALPUFF model of March 2006
vintage and the CALPOST model of
April 2006 vintage.) These older
versions pre-date the latest Model
Change Bulletin (MCB–D) of June 23,
2007. Since the analysis for the five
Wyoming power plants was performed
in February thru April 2012, we
question why the older version was
used and not the current CALPUFF 5.8
version, which was approved as the
guideline version in June of 2007. We
do not recommend use of the older
versions of CALPUFF and CALPOST.
Response: As described in this action,
our previous modeling continued to use
the State’s Protocol, including the older
model versions, to maintain consistency
with the State’s modeling results.
However, in this final action, we
adopted a new modeling protocol that
uses the current regulatory versions of
the models, including the Model Change
Bulletin suggested by the commenter.
We determined that it was appropriate
to adopt an updated modeling protocol
because we made other significant
changes in the State’s modeling
approach, and because we remodeled all
emissions scenarios, there was no longer
a need to use older model versions for
consistency of comparison of our
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limited gap filling model results to the
State’s original modeling.
Comment: EPA should have used the
most recent version of CALPUFF, or at
a minimum, should have used the
version that EPA requires for other
regional haze SIPs. EPA has taken the
position that CALPUFF Version 5.8
must be used for regional haze
modeling. 77 FR 42834, 42854.
However, EPA’s unit-specific CALPUFF
modeling in Wyoming, completed in
April 2012, used CALPUFF Version
5.711a (originally released in 2004).
Version 5.711a is eight years old, and
several CALPUFF versions behind
Version 5.8. While PacifiCorp believes
the more modern and realistic
CALPUFF Version 6.42 should be used,
at a minimum EPA must abide by its
own position and use Version 5.8 in
evaluating the Wyoming regional haze
SIP, which it failed to do. According to
EPA’s own statements, EPA’s own
modeling results should be discarded
because EPA used an improper
‘‘alternative model’’ in Wyoming.
EPA should have used the most recent
version of CALPUFF (Version 6.42) in
Wyoming because it produces more
realistic and accurate results. Version
6.42 contains needed refinements, such
as a better ‘‘chemistry’’ module known
as ISORROPIA (Version 2.1). CALPUFF
Version 6.42 is more accurate because,
as the FLMs have noted, Version 5.8
does not have the required settings to
perform the new Method 8 visibility
analysis. Additionally, CALPUFF
Version 6.42 has been maintained by
TRC, Inc., a private contractor, and has
had many bug fixes and enhancements
not included in CALPUFF Version 5.8.
Most importantly, the previous
chemistry modules used in Version 5.8
(and in the 5.711a Version EPA used
here) also have been shown to
overestimate nitrate concentrations in
Wyoming by a factor of 3–4 and
substantial improvements have been
made to eliminate this over-prediction
using the ISORROPIA module.
Despite all these advancements in
modeling and modeling science, EPA
conducted its modeling for its regional
haze FIP in 2012 using the same (now
outdated) CALPUFF version that
PacifiCorp and Wyoming used five years
ago, which has been shown to
overestimate results by 300% to 400%.
Rejecting Wyoming’s modeling, and
then using the same, outdated modeling
approach, is arbitrary and capricious.
Response: As described in previous
responses, we previously used the same
modeling protocol adopted by the State
for the purpose of our limited, gap
filling modeling, so that we would have
a consistent basis for comparison with
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the State’s modeling. In this action we
have updated the protocol to use the
current regulatory versions of the
models including CALPUFF version 5.8.
We did not use CALPUFF Version
6.42 because this version of the model
has not been approved by EPA for
regulatory use. EPA relied on version
5.8 of CALPUFF because it is EPAapproved version in accordance with
the Guideline on Air Quality Models
(‘‘GAQM’’, 40 CFR 51, Appendix W,
section 6.2.1.e). EPA updated the
specific version to be used for regulatory
purposes on June 29, 2007, including
minor revisions as of that date. The
approved CALPUFF modeling system
includes CALPUFF version 5.8, level
070623, and CALMET version 5.8 level
070623. CALPUFF version 5.8 has been
thoroughly tested and evaluated, and
has been shown to perform consistently
with the initial 2003 version in the
analytical situations for which
CALPUFF has been approved. Any
other version, and especially one with
such fundamental differences in its
handling of chemistry, would be
considered an ‘‘alternative model’’,
subject to the provisions of GAQM
section 3.2.2(b), requiring full model
documentation, peer-review, and
performance evaluation. No such
information for the later CALPUFF
versions that meet the requirements of
section 3.2.2(b) has been submitted to or
approved by EPA. Experience has
shown that when the full evaluation
procedure is not followed, errors that
are not immediately apparent can be
introduced along with new model
features. For example, changes
introduced to CALMET to improve
simulation of over-water convective
mixing heights caused their periodic
collapse to zero, even over land, so that
CALPUFF concentration estimates were
no longer reliable.112
The change from CALPUFF version
5.8 to CALPUFF 6.4 is not a simple
model update to address minor issues,
but a significant change in the model
science that requires its own rulemaking
with public notice and comment before
it can be relied on for regulatory
purposes.
Furthermore, it should be noted that
the U.S. Forest Service and EPA review
of CALPUFF version 6.4 results for a
limited set of BART applications
showed that differences in its results
from those of version 5.8 are driven by
two input assumptions not associated
112 ‘‘CALPUFF Regulatory Update’’, Roger W.
Brode, Presentation at Regional/State/Local
Modelers Workshop, June 10–12, 2008; https://
www.cleanairinfo.com/
regionalstatelocalmodelingworkshop/archive/2008/
agenda.htm.
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with the chemistry changes in 6.4. Use
of the so-called ‘‘full’’ ammonia limiting
method and finer horizontal grid
resolution are the primary drivers in the
predicted differences in modeled
visibility impacts between the model
versions. These input assumptions have
been previously reviewed by EPA and
the FLMs and have been rejected based
on lack of documentation, inadequate
peer review, and lack of technical
justification and validation.
Comment: The commenter states that
EPA treats the results from the
CALPUFF as being capable of accurately
predicting visibility improvements
down to the tenths or hundredths of a
deciview, but that the model does not
accurately predict visibility impacts at
this level.
Response: As described in response to
other comments, EPA recognized that
there is uncertainty in the CALPUFF
results, and EPA addressed this
uncertainty by using the modeled 98th
percentile visibility impairment rather
than the maximum visibility
impairment. EPA considers model
changes on the order of tenths of a
deciview to be useful for informing the
BART decision process, consistent with
BART modeling performed by other
EPA regions and states.
Comment: PacifiCorp presented
substantial information supporting the
need to use improved and updated
versions of the models and provided
substantial information on the effects
that the nitrogen oxides to nitrogen
dioxide conversion rate and background
ammonia concentrations have on
modeled visibility impacts.
Response: We agree with the
comment that the background ammonia
concentration has a significant effect on
model predicted visibility impacts. As
described elsewhere in this action, we
reviewed recent ambient monitoring
data for ammonia and particulate
ammonium, and concluded that the
original background ammonia
concentration of 2 ppb was inconsistent
with the IWAQM Phase 2 report and
monitoring data for estimating visibility
impacts in Wyoming, especially in the
western portion of the State. In the
modeling results included in this action,
we considered the default value of 0.5
ppb and also applied a seasonally
varying background ammonia
concentration in western Wyoming that
was based on measurements from 2006
to 2011 of total ammonia and particulate
ammonium at Pinedale, Wyoming.113
We also reduced the background
ammonia concentration to 1 ppb in the
eastern portion of the State, and for both
113 Li
et al. 2013
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parts of the State we used an ammonia
limiting correction for modeling
multiple units from a single BART
source to avoid double counting of the
available ammonia. The use of more
realistic ammonia background
concentrations, the ammonia limiting
correction, and the use of the 98th
percentile modeled impact address the
concern that the CALPUFF model could
overestimate visibility impacts.
Comment: One commenter stated that
we underestimated the background
ammonia concentration in the
CALPUFF modeling, and cited the
IWAQM Phase 2 recommendations for
default ammonia concentrations for
grasslands, forest lands and arid lands,
respectively, of 10, 0.5 and 1 ppb, at 20
degrees Celsius. The commenter stated
that, because land use type can vary
across the large domains used in the
CALPUFF modeling, it would be
appropriate to calculate a weighted
average of the background ammonia
based on the fractional land use type in
the model domain.
Response: We disagree with this
comment. The IWAQM Phase 2 report
does not recommend calculating a
weighted average of default ammonia
concentration based on regional
variation in land use types. The
commenter provides no regulatory basis
for use of a weighted average.
Comment: One commenter stated that
the IWAQM recommended default
background ammonia recommendations
do not specifically account for strong
point/area sources of ammonia, such as
cattle feedlots, which are also scattered
throughout the modeling domain and
which generally add to the background
ammonia levels. This commenter stated
that some areas of the modeling domain,
namely northeastern Colorado, are
described as ‘‘ammonia rich’’. For BART
source analyses in Colorado, the
recommended background ammonia
value from the Colorado Department of
Public Health and Environment
(CDPHE) is 44 ppb, based on
measurements conducted during the
Northern Front Range Air Quality Study
(NFRAQS), and therefore the Wyoming
DEQ/EPA background ammonia
concentration of 2 ppb might not carry
sufficient ammonia for an accurate
modeling assessment of visibility
impacts within certain Colorado Class I
areas.
Response: We disagree with the
comment that large point/area sources
are not included in estimates of
background ammonia concentrations.
While concentrations of ammonia of
several hundred ppb can be observed
near a cattle feedlot, these
concentrations are not typical of
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regional background concentrations.
Additionally, dispersion and vertical
mixing occur in plumes of air
transported downwind of large
emissions sources, and the resulting
dilution of ammonia results in lower
concentrations as the plume is
transported downwind of the source
area. Therefore, ambient ammonia
concentrations are generally greatly
reduced downwind from the source.
Moreover, ammonia has a short
atmospheric lifetime of a few hours to
a few days,114 and removal of ammonia
by deposition further reduces the
concentration downwind of the source
area. Therefore, it would be
inappropriate to estimate background
ammonia levels by measuring ammonia
concentrations close to a large ammonia
emissions source. Background
concentrations of air pollutants are
generally estimated using ambient
monitoring data at background sites that
are specifically selected such that there
is no direct influence by large nearby
point or areas sources.115 Therefore,
background monitoring data do
explicitly include the contributions of
emissions from large point and area
sources by providing a direct
measurement of the ambient
concentration after transport, dilution
and removal processes operate on the
emissions from the source.
The commenter also cites modeling
performed by the CDPHE and ammonia
measurements made during the
NFRAQS studies. As discussed in
another response, CDPHE performed a
CALPUFF model sensitivity study to
evaluate the effect of background
ammonia on model predicted nitrate
concentrations, and found that the
CALPUFF model was insensitive to
variations in background concentrations
greater than 10 ppb and became
progressively more sensitive to
background NH3 as it was reduced from
10 to 0 ppb.116 The NFRAQS study
reported measured ammonia
concentrations in the Denver
metropolitan area, and these
measurements are not representative of
background ammonia concentrations in
114 Langford
et al.
example, see EPA guidance documents
that discuss methods for estimating background
NO2 concentrations: ‘‘Additional Clarification
Regarding Applicability of Appendix W Modeling
Guidance for the 1-hour NO2 NAAQS’’
116 Supplemental BART Analysis CALPUFF
Protocol for Class I Federal Area Visibility
Improvement Modeling Analysis, DRAFT, revised
Aug 19, 2010, Colorado Department of Public
Health and Environment. (CDPHE) Air Pollution
Control Division Technical Services Program, 4300
Cherry Creek Drive South, Denver, Colorado 80246,
pages 26–33.
115 For
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rural and remote areas of central
Colorado or western Wyoming.
Comment: The commenter states that
Wyoming has conducted its regional
haze SIP based on the modeling
protocols and versions available at the
time its regional haze SIP was
completed. Because of this, there are
limitations associated with the results
obtained. However, in proposing its
regional haze SIP, Wyoming has
evaluated the model output with an
understanding of the model’s
limitations. Wyoming then applied its
judgment, as encouraged and required
by EPA’s guidelines and the CAA,
which helped to mitigate the issues
associated with models that over-predict
the visibility improvement associated
with BART controls being added. In
contrast, EPA gives no consideration to
the limitations of the models it uses. In
the absence of using good judgment to
deal with over-predictive results, it is
critical that EPA use the most up-to-date
and scientifically accurate models
available.
We also received related comments
that states have significant modeling
discretion to which EPA failed to grant
the proper deference. One commenter
pointed out that the BART Guidelines
recognize that states can make
judgments regarding the use of
modeling results due to the very real
problems with CALPUFF, including its
overestimation of visibility
improvement. As EPA itself has stated,
Wyoming should be free to make its
own judgment about which modeling
approaches are valid and appropriate.
70 FR 39123. Another commenter
pointed to the statement that ‘‘we must
permit States to take into account the
degree of improvement in visibility that
would result from imposition of BART
on each individual source when
deciding on particular controls.’’ 70 FR
39107, 39129. Another commenter
stated that EPA failed to allow Wyoming
to account for CALPUFF’s
overestimation of NOX impacts, and
therefore, EPA is not affording
Wyoming’s BART decisions the proper
deference when it comes to the
modeling and applying the modeling
results.
Response: As discussed elsewhere in
this document in greater detail,
Congress crafted the CAA to provide for
states to take the lead for implementing
plans, but balanced that decision by
requiring EPA to approve the plans or
prescribe a federal plan should the state
plan be inadequate. Our action today is
consistent with the statute. As also
discussed elsewhere in this document,
we agree that there are limitations in the
original modeling performed by the
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state, and therefore, it was necessary to
perform new modeling using more
realistic background ammonia
concentrations, default values, and
updated model versions to provide a
sound basis for evaluating BART source
visibility impacts. Our revised modeling
is consistent with the BART Guidelines
and with visibility modeling guidance
in the IWAQM Phase 2 report, and we
believe that the revised modeling
constitutes a sound basis for evaluating
visibility impacts of BART sources and
in fact is supportive of Wyoming’s SIP
with respect to sources where ammonia
background makes a significant
differences.
Comment: The commenter states that
EPA should have used the most recent
version of CALPUFF (Version 6.42) in
Wyoming because it produces more
realistic and accurate results and
because Version 5.8 does not have the
required settings to perform the new
Method 8 visibility analysis.
Response: As described in response to
another comment, we used CALPUFF
version 5.8 because this is the approved
regulatory version of the model, while
CALPUFF version 6.42 has not been
approved. CALPUFF version 5.8 does
allow the option of using the Method 8
visibility analysis, and as described in
our modeling protocol, we used Method
8 for our analysis. The availability of
Method 8 in CALPUFF version 5.8 was
one of the reasons that we determined
it was important to perform new
modeling using the current regulatory
version of the model, rather than
continuing to rely on the original
protocol adopted by the State in 2006,
as we had done in our previous
proposal.
Comment: EPA used a different
background ammonia number for
modeling than it requires of the states,
and ignored current science on
background ammonia. Regional haze
modeling, and the resulting predicted
visibility improvement, is greatly
influenced by the background ammonia
number used in the model. EPA
improperly used a constant 2 ppb
background ammonia number for the
Wyoming BART modeling. EPA has not
provided any scientific proof showing
the constant 2 ppb ammonia number is
appropriate for Wyoming. The 2 ppb
ammonia value overestimates visibility
improvement, contrary to the approach
used by Wyoming Land Use, IWAQM
Guidance, WRAP protocols, and
elsewhere.
Commenter suggests that the WRAP
recommended the use of 1 ppb of
ammonia year round for states in the
region to account for seasonal
variability. EPA has required states to
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use 1 ppb of background ammonia when
conducting regional haze modeling. 76
FR 52434 (New Mexico criticized for not
using 1 ppb background ammonia). At
a minimum EPA should follow its own
guidelines and use 1 ppb of background
ammonia when conducting CALPUFF
unit-specific modeling.
However, the ‘‘best’’ science requires
the use of ‘‘variable ammonia’’
background numbers. IWAQM
recommends ammonia background
numbers of 0.5 ppb for forest, 1 ppb for
dry/arid lands, and 10 ppb for
agriculture/grassland. Given its
geographic location and elevation
levels, Wyoming undergoes seasonal
swings of dry-hot summers and snow
covered ground in the winter. Therefore,
the use of a single ammonia
concentration for the entire year in a
state where the land use and land cover
changes significantly between seasons
results in overestimation of visibility
improvements. This is particularly true
in winter when agricultural activity is
minimal and meteorological conditions
make visibility calculations particularly
sensitive to ambient ammonia
concentrations. EPA has approved the
use of variable gaseous ammonia
concentrations before, including the
‘‘Addendum to Modeling Protocol for
the Proposed Desert Rock Generating
Station’’ and should have used them
when conducting the CALPUFF
modeling for Wyoming.
Sensitivity tests on ambient ammonia
concentrations were performed by the
CDPHE for an area in northwest
Colorado. The analysis demonstrated
that visibility calculations performed at
Mount Zirkel Wilderness Area in
northwest Colorado had limited impact
when ambient ammonia concentrations
were reduced from 100 to 1 ppb, but
there was a significant reduction in
visibility impacts when concentrations
were further reduced to 0.1 ppb.
Given the evidence presented above,
the use of the monthly varying ammonia
would provide accurate estimates of
visibility impacts from the PacifiCorp
regional haze units. EPA’s failure to use
variable background ammonia in its
modeling is arbitrary and capricious.
Response: We agree that the 2 ppb
constant background ammonia
concentration is inconsistent with the
IWAQM Phase 2 report default values
and monitored data. This value was
adopted by the State in 2006 before
more reliable ammonia and particulate
ammonium measurements were
available in Wyoming. As described in
this action, we modeled using
seasonally varying background
ammonia concentrations in western
Wyoming based on 5 years of
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monitoring data,117 and we also
modeled using the IWAQM default
value of 0.5 ppb for forests. In eastern
Wyoming we adopted a constant 1 ppb
ammonia concentration based on the
IWAQM guidance. We used an
ammonia limiting correction for BART
sources with multiple units throughout
the State. While robust, long term
monitoring data of ammonia and
particulate ammonium are not available
in eastern Wyoming, the BART sources
in eastern Wyoming, and the South
Dakota Class I areas where they
contribute the greatest visibility
impairment, are located closer to areas
of Nebraska and the Dakotas which have
large agricultural sources of ammonia
emissions. Moreover, the IMPROVE
monitoring at the South Dakota Class I
areas show much higher winter
concentrations of ammonium nitrate
than do Class I areas in western
Wyoming. Therefore, we believe it is
appropriate to adopt higher background
ammonia concentrations in eastern
Wyoming than in western Wyoming,
and we used a constant 1 ppb ammonia
concentration in eastern Wyoming,
consistent with the IWAQM
guidance 118 for arid lands and also
consistent with the WRAP Protocol.119
Comment: EPA made a modeling error
in Wyoming when it used CALPOST
version 5 with Method 6. FLMs
recommended in 2000 the use of
Method 6 to determine visibility
impacts from BART eligible sources.
However, for any recent PSD
application and BART modeling since
2010, EPA has requested that Method 8
be used for determining impacts on
visibility at nearby Class I areas.
The previously preferred Method 6
simply computes background light
extinction using monthly average
relative humidity adjustment factors
particular to each Class I area applied to
background and modeled sulfate and
nitrate. Six years after the development
of Method 6 in 1999, EPA released
enhancements to the background light
extinction equations, which use the
revised IMPROVE variable extinction
efficiency formulation. These
enhancements take into account the fact
that sulfates, nitrates and organics and
other types of particles have different
117 Li
et al., 2013.
Workgroup On Air Quality
Modeling (IWAQM) Phase 2 Summary Report And
Recommendations For Modeling Long Range
Transport Impacts (EPA–454/R–98–019), EPA
OAQPS, December 1998.
119 Tonnesen, G., Wang, Z., Morris, R., Hoats, A.,
Jia, Y., Draft Final Modeling Protocol, CALMET/
CALPUFF Protocol for BART Exemption Screening
Analysis for Class I Areas in the Western United
States, Submitted to the Western Regional Air
Partnership, August 15, 2006.
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118 Interagency
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light extinction coefficients. Also, the
background concentrations at each Class
I area have been updated by EPA to
reflect natural background visibility
condition estimates for each Class I area
for each type of particle. Additionally,
relative humidity adjustment factors
have been tailored separately for small
particles, large particles, and to account
for sea salt background concentrations.
These new enhancements to the
calculation method, called Method 8,
greatly improve the accuracy of the
estimated visibility impact. Method 8
was added to CALPOST in 2008 and
was adopted as the preferred option for
determining impacts on visibility by the
FLMs in their ‘‘Federal Land Managers
Air Quality Related Values Work Group
Guidance Document’’ in 2010 (FLAG
2010). The applicable background
concentrations and relative humidity
adjustment factors using Method 8 for
each Class I area are identified in the
FLAG 2010 document.
Despite the update to Method 8 in
2008 and the stated preference by the
FLMs in 2010 to use Method 8, EPA
conducted the Wyoming BART
modeling in 2012 using the long
outdated and scientifically inferior
Method 6. EPA’s use of Method 6, and
not Method 8, is arbitrary and
capricious.
Response: We agree that it is
preferable to use Method 8 rather than
Method 6 for evaluating visibility
impacts based on the recommendation
of the FLMs in FLAG 2010.120 The older
CALPUFF version 5.711 that was
adopted in the State’s original modeling
protocol in 2006 did not have the option
of using Method 8. In our previous
modeling we adopted the State’s
original protocol to maintain a
consistent basis of comparison with the
State’s modeling results. In this final
action, we adopted an updated
modeling protocol using the current
regulatory version of the model, which
allows the use of Method 8, and we
used Method 8 for the analysis of
visibility impacts.
Comment: We received numerous
comments that EPA incorrectly used the
maximum annual visibility impacts
occurring during any given year of the
2001–2003 baseline period over which
the Wyoming visibility models are run.
Commenters asserted that standard
practice has been, and continues to be,
to average the results over the three year
period as the three year average is a
120 Federal Land Managers’ Air Quality Related
Values Work Group (FLAG) Phase I Report—
Revised (2010).
Natural Resource Report NPS/NRPC/NRR—2010/
232.
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5119
more robust value than the single year
value used by EPA, and thus EPA
should use longer term data. One
commenter pointed out that consistent
with the principle of using longer-term
averages, baseline visibility conditions
under the RHR are determined by taking
the average degree of visibility
impairment for the most and least
impaired days for each of calendar years
2000 through 2004, and averaging the
five annual values.
Response: We disagree with this
comment. In our review of the
CALPUFF modeling results presented
by Wyoming, we cited the change in the
maximum 98th percentile impact over
the modeled three year meteorological
period (2001–2003). As the 98th
percentile value is intended to reflect
the 8th high value in any year, it already
eliminates seven days per year from
consideration in order to account for
short-term events, unusual
meteorological conditions, and any
over-prediction bias in the model. We
also note that our approach is consistent
with the method used by Wyoming in
identifying subject-to-BART sources,
where a source is exempt from BART
only if the modeled 98th percentile
change is less than 0.5 deciview at all
Class I areas for each year modeled.121
That is, whether a source is subject to
BART is dependent on the maximum
98th percentile over the three year
modeled meteorological period, not the
average across the three year period. We
find that it is reasonable to use the same
approach when considering the
visibility improvements associated with
control options. Finally, we note that
this approach is consistent with our
consideration of visibility improvement
in other actions, such as our FIP for
Montana.
Comment: EPA’s use of the maximum
values in its BART NOX determinations
for its regional haze FIP causes inflated
visibility impacts and over-estimated
improvements being used. For example,
if EPA were to run its approved models,
used its approved ammonia values for
the western states, and used the average
visibility impact over the three years
rather than a maximum impact for a
single year, the incremental visibility
impact between installing LNB
technology and SNCR at Wyodak and
Dave Johnston Unit 3 drops to just 0.09
deciview. Instead, EPA has used an
improper evaluation to create an
inflated visibility improvement of 0.15
and 0.17 delta deciview to justify the
installation of the SNCR. As a result,
EPAs’ BART NOX evaluations are
121 Chapter 6, Section 9(d)(i)(C) of the Wyoming
Air Quality Standards and Regulations.
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invalid. The modeling results reported
by Mr. Paine using the actual BART
limits include values for each of the
meteorological years 2001, 2002 and
2003, as well as the average values for
the three years. All of the values signify
a negligible visibility improvement from
SNCR.
Response: We have addressed each
aspect of this comment in separate
responses to comments. In our previous
proposal we performed CALPUFF
model simulations consistent with the
approach specified in the Wyoming
protocol, but in this action we adopted
updated model versions and used lower
ammonia background concentrations
that are consistent with monitoring data
and IWAQM Phase 2 report. Regardless,
as discussed in section IV, in
consideration of our revised cost of
compliance and visibility impact
analyses, and of the remaining BART
factors, we have changed our final NOX
BART determinations for both of the
units in question. We are no longer
requiring SNCR for either Wyodak or
Dave Johnston Unit 4.
Comment: EPA’s use of the
cumulative deciview improvement from
several Class I areas overestimates the
visibility improvement which may
reasonably be anticipated because
visibility impacts from a BART source
may occur on different days at each
Class I area. Adding the numbers in
Tables 47, 54, and 56 of EPA’s proposed
regional haze FIP leads to the
impression that a perceptible visibility
improvement will occur, when in reality
none of the modeled visibility
improvements would be perceptible to
the human eye.
Response: We disagree with this
comment. In evaluating the visibility
improvement associated with various
control options, EPA interprets the CAA
to require consideration of visibility
improvement at all impacted Class I
areas. Consideration of improvement at
multiple Class I areas, as opposed to just
benefits at the most impacted Class I
area, has often been described as
‘‘cumulative visibility improvement.’’
Despite this terminology, however, an
analysis of cumulative visibility
improvement does not necessarily
require that the deciview improvement
at each area be summed together. While
states or EPA are free to take such a
quantitative approach, they are also free
to use a more qualitative approach.
Here, we chose to rely primarily on the
visibility improvement at the most
impacted Class I area, while also
considering the number of additional
Class I areas that would see
improvement, as well as the level of
improvement at each area. We did not
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expressly rely on a summation of
visibility benefits across Class I areas, as
we have done in other regional haze
actions, although, as the commenter
points out, this metric was included in
some tables. Contrary to the
commenter’s assertion, however, a
summation of visibility benefits is not
intended to suggest that individually
imperceptible levels of improvement are
somehow perceptible, but rather to
provide a single metric that can
simultaneously capture both the number
of Class I areas affected and the
magnitude of improvement at those
areas for comparison purposes.
Moreover, we note that visibility
improvement does not need to be
perceptible to be deemed significant for
BART purposes. We have responded in
more detail to concerns regarding
perceptibility elsewhere in this
document.
Comment: The commenter states that
EPA’s cumulative visibility analyses
ignore the discretion given to states in
70 FR 39107; Id. at 39123 (emphasis
added); see also 77 FR 24768, 24774
(Apr. 25, 2012)
Response: As stated above, EPA
primarily relied on the benefits at the
area with the greatest visibility
improvement from controls, but we also
considered impacts and benefits at
nearby areas included in the modeling
analysis. The consideration of visibility
benefits over multiple Class I areas is a
useful metric that can further inform a
BART determination.
Comment: The BART rule provides no
support for EPA’s ‘‘summation of
cumulative impacts’’ approach. Rather,
the BART rule makes clear that the
initial focus is expected to be on the
‘‘nearest Class I area’’ to the facility in
question. 70 FR 39104, 39162 (Separt 6,
2005). The BART rules indicate that it
is appropriate to take account impacts at
not only the nearest Class I area but also
impacts at other nearby Class I areas,
not for the purposing of summing
impacts at all of those areas, but rather
for the purpose of ‘‘determin(ing)
whether effects at those (other) areas
may be greater than at the nearest Class
I area.’’ Id. The BART rule states: ‘‘If the
highest modeled effects are observed at
the nearest Class I area, you may choose
not to analyze the other Class I areas any
further as additional analyses might be
unwarranted.’’ Id.
Response: See our response to
comments above. In addition, the BART
Guidelines provide that states, or EPA
in lieu of the state, have discretion on
how to assess visibility impacts.
Comment: The commenter states that
the BART rule does not preclude a state
from taking into account, as part of a
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BART assessment for a given facility,
visibility impacts projected to occur in
two or more Class I areas that are
attributable to that facility’s emissions.
However, nothing in the rules requires
such an analysis, and such analyses are
deceptive when used in a cumulative
fashion. EPA did not have the authority
to disapprove Wyoming’s visibility
improvement analyses on the grounds
that EPA prefers a different approach
than the lawful and permissible
approach taken by Wyoming. See Train
v. Natural Res. Def. Council, Inc., 421
U.S. 60, 79 (1975).
Response: See our response to
comments above and elsewhere in this
document (e.g., Legal Issue section)
regarding EPA’s oversight authority.
Comment: EPA has improperly failed
to account for the very few number of
days of visibility impacts or the seasonal
timing of when those few impacts occur.
Response: EPA recognizes that the
BART Guidelines allow states to
consider the timing of impacts in
addition to other factors related to
visibility impairment. However, states
are not required to do so, and EPA is not
required to substitute a source’s desired
exercise of discretion for that of the
states. Furthermore, when promulgating
a FIP, EPA stands in the shoes of the
state. In that capacity, EPA is not
required to consider the seasonality of
impacts and has chosen not to do so
here. Taking into account visitation
contradicts the goal of the regional haze
rule of improving visibility on the 20
percent best and worst days. Indeed,
EPA believes that the experiences of
visitors who come to Class I areas
during periods other than the peak
visitation season are important and
should not be discounted.
Comment: A review of the unitspecific CALPUFF EPA modeling
results developed for the Mount Zirkel
Wilderness Area provides a vivid
example of the over-estimation of
visibility improvement that EPA is
relying on to justify the installation of
hundreds of millions of dollars in
additional controls. The unit specific
CALPUFF modeling would indicate that
adding SCR to these units would
improve visibility in Mount Zirkel by
over seven deciviews.
However, the monitored data from
2001–2003 at Mount Zirkel tells a
completely different story. This is the
same time period used in the CALPUFF
models to develop the deciview impacts
for each Wyoming BART-eligible unit
and to project the visibility
improvements associated with the
addition of control devices.
Looking at the three-year average
monitored results, and assuming that
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the nitrates associated with the
emissions from all sources (not just the
BART-eligible EGUs) are completely
eliminated, only a 0.94 deciview
improvement would be expected. EPA
attempts to justify over a billion dollars
in controls at eight PacifiCorp units by
assuming more than seven deciviews of
improvement could be obtained from
these eight units when the actual
monitored data indicates that only a
0.94 deciview improvement would be
possible if all nitrate was removed from
all sources. In essence, EPA’s regional
haze FIP fails to recognize that, given
the monitored nitrate impacts, the
modeled visibility impacts are
obviously grossly exaggerated.
Response: We agree with some of
these concerns—that the original
modeling performed by the State and
EPA used a high background ammonia
concentration and did not correct for
ammonia limiting conditions. This
particularly affected the model results
in the western part of Wyoming and
Class I areas such as Bridger Wilderness
Area.
We have addressed this concern by
adopting a new modeling protocol that
makes several improvements in the
model results, including the use of the
current regulatory version of the model,
the use of Method 8 to assess visibility
impacts, the use of lower background
ammonia concentrations, and ammonia
limiting correction for BART sources
with multiple units. We note that the
model overprediction in our reproposed modeling analyses occurred at
Class I areas affected by BART sources
in western Wyoming, in the region in
which monitoring data showed strong
seasonal variability in ammonia
concentrations. In contrast, modeled
nitrate impacts from BART sources in
eastern Wyoming were significantly
lower than observed nitrate
concentrations at IMPROVE sites at
Wind Cave and Badlands in western
South Dakota.
There are several factors that make it
challenging to directly compare
CALPUFF results to measured
concentrations at IMPROVE monitoring
sites at Class I areas. Most significantly,
the monitor operates every third day,
while the model predicts concentration
each day. Moreover, modeled visibility
impacts from multiple BART sources
cannot be summed and directly
compared to measured data as all BART
sources are unlikely to have their largest
impacts on the same Class I area on the
same day. Additionally, the model 98th
percentile impact should be compared
to the maximum observed monitoring
data because the highest 2% of model
impacts are discarded to address
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concerns that the model can overpredict
visibility impacts.
Comment: The commenter cites a
study by Terhorst and Berkman which
compared CALPUFF model predicted
impacts of the Mojave Power Station at
the Grand Canyon to observed impacts
after the facility was closed in 2005. The
study concluded that there was virtually
no evidence that the (Mojave) closure
improved visibility in the Grand
Canyon, and the commenter cites this
conclusion as evidence of the
unreliability of the CALPUFF model.
Response: We disagree that the
Mohave Power Plant study raises
questions about CALPUFF’s reliability.
The Nevada Division of Environmental
Protection performed CALPUFF
modeling to estimate the contribution of
the Mohave Power Plant to visibility
impairment at Grand Canyon National
Park. Consistent with the BART
Guidelines, the State used the CALPUFF
model to evaluate the Mohave Power
Plant contribution to visibility
impairment relative to natural visibility
conditions. Subsequently, after the
Mohave Power Plant ceased operating,
Terhorst and Berkman analyzed changes
in monitored sulfate concentrations at
the Grand Canyon and calculated the
visibility impacts of those changes
relative to current degraded visibility
conditions. Terhorst and Berkman
incorrectly concluded that the State’s
previous CALPUFF modeling
overpredicted the Mohave Power Plant
visibility impacts because Terhorst and
Berkman failed to compare their results
to natural visibility conditions. EPA
considered and rejected comments on
the proposed BART Guidelines that
visibility impacts should be evaluated to
relative to current degraded visibility
conditions and concluded that ‘‘[u]sing
existing conditions as the baseline for
single source visibility impact
determinations would create the
following paradox: the dirtier the
existing air, the less likely it would be
that any control is required.’’ (70 FR
39124). Because Terhorst and Berkman
failed to compare observed changes in
sulfate concentration to natural
visibility conditions, their analysis does
not support the commenter’s statement
that CALPUFF is unreliable. This flaw
in their analysis has also been
recognized in a paper that responded to
their analysis.122 Finally, as presented
above, the use of the CALPUFF model
122 W.H. White, R.J. Farber, W.C. Malm, M.
Nuttall, M.L. Pitchford, B.A. Schichtel, Comment
on ‘‘Effect of coal-fired power generation on
visibility in a nearby National Park (Terhorst and
Berkman, 2010)’’, Atmospheric Environment 55
(2012) 173–178. doi:10.1016/
j.atmosenv.2012.02.076.
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5121
for regional haze is a settled manner for
which the time for judicial review has
passed.
Comment: The commenter states that
EPA’s own studies document that
CALPUFF overstates results and cites a
May 2012 EPA sponsored study of
CALPUFF that found ‘‘the current and
past CALPUFF model performance
evaluations were consistent with
CALPUFF tending to overestimate the
plume maximum concentrations and
underestimate plume horizontal
dispersion.’’
Response: In the BART Guidance,
EPA recognized concerns that CALPUFF
can overpredict visibility impacts in
some cases, and therefore, as explained
above, adopted the use of the 98th
percentile modeled impact, rather than
the maximum modeled impact, to
address this concern.
Comment: EPA appears to take
contrary positions in Oklahoma, where
it modeled all visibility impairing
pollutants together, and Wyoming,
where EPA said that, based on the
State’s modeling, EPA ‘‘could not
ascertain what the visibility
improvement would be from an
individual NOX or PM control option.’’
Response: It appears that the
commenter has confused (1) whether all
pollutants were modeled together; and
(2) whether all emission reductions
were modeled together. All pollutants
were modeled together both in modeling
performed by Wyoming and by EPA for
BART sources in Wyoming and
Oklahoma, consistent with IWAQM
Phase 2 report recommendations and
with the State of Wyoming modeling
protocol. The additional modeling
performed by EPA was designed to
evaluate visibility improvements from
certain emissions reduction
technologies; specifically, to compare
the incremental benefits of SCR and
SNCR. Each of these model simulations
by EPA also included all other visibility
impairing pollutants, so the approach
used by EPA in Wyoming and
Oklahoma is consistent.
Comment: EPA found that SCR
provided only a 0.36 delta deciview
incremental visibility improvement for
Dave Johnston Unit 3, using EPA
modeling, with an incremental cost of
$7,163.00 per ton. 78 FR 34777–34778.
EPA failed to justify in its proposed rule
how a 0.36 delta deciview
improvement, or approximately onethird that humanly detectible, justifies
the tremendous cost of SCR. Likewise,
EPA found that installing SNCR at Dave
Johnston Unit 4 results in an
incremental 0.11 delta deciview
improvement over Wyoming’s BART
determination at an incremental cost of
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$4,655. 78 FR 34781–34782. The alleged
incremental visibility benefit of
installing SNCR at Wyodak is 0.12 delta
deciview at an incremental cost of
$3,725 per ton. 78 FR 34784–34785.
EPA provides no justification for
requiring such tremendous costs for
such an inconsequential visibility
improvement that likely falls within
CALPUFF’s margin of error. EPA’s
modeling approaches are inconsistent
because EPA has determined in other
states that visibility improvements
greater than those used to justify SNCR
at Wyodak are too small or
inconsequential to justify additional
pollution controls. See 77 FR 24794
(0.27 deciview improvement termed
‘‘small’’ and did not justify additional
pollution controls in New York); 77 FR
11879, 11891 (0.043 to 0.16 delta
deciview improvements considered
‘‘very small additional visibility
improvements’’ that did not justify NOX
controls in Mississippi); 77 FR 18052,
18066 (agreeing with Colorado’s
determination that ‘‘low visibility
improvement (under 0.2 delta
deciview)’’ did not justify SCR for
Comanche units)). Tellingly, the ‘‘low
visibility improvements’’ that Colorado
found at the Comanche units not to
justify post-combustion NOX controls,
as agreed to by EPA, were 0.17 and 0.14
delta deciview. 77 FR 18066. In
Montana, where EPA issued a regional
haze FIP directly, it found that a 0.18
delta deciview improvement to be a
‘‘low visibility improvement’’ that ‘‘did
not justify proposing additional
controls’’ for SO2 on the source. 77 FR
23988, 24012. Here, EPA’s actions
requiring additional NOX controls based
on little to no additional visibility
improvement are arbitrary and
capricious, especially when EPA did not
require additional NOX controls in other
states based on similar visibility
improvements. This is particularly true
in Montana where EPA had direct
responsibility for the regional haze
program.
Response: We disagree that visibility
improvements at Dave Johnston Unit 3
and Wyodak are ‘‘too small or
inconsequential to justify additional
pollution controls.’’ While the visibility
benefits at these units are less than what
is generally considered perceptible (1.0
deciview), they are not so low as to
preclude selection of the associated
controls without any consideration of
the remaining BART factors. The BART
Guidelines are clear that states should
consider visibility impacts that are less
than perceptible: ‘‘Even though the
visibility improvement from an
individual source may not be
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perceptible, it should still be considered
in setting BART because the
contribution to haze may be significant
relative to other source contributions in
the Class I area. Thus, we disagree that
the degree of improvement should be
contingent upon perceptibility. Failing
to consider less-than-perceptible
contributions to visibility impairment
would ignore the CAA’s intent to have
BART requirements apply to sources
that contribute to, as well as cause, such
impairment.’’ 70 FR 39129. When the
visibility improvements are considered,
we continue to find that this level of
improvement, when considered along
with the other statutory factors, justifies
the selected BART controls.
Finally, regarding commenter’s
assertions that we are being
inconsistent, because the commenter is
only specific about visibility
improvement, it is not possible for EPA
to address in this response any specific
concerns. As articulated in our
proposed rulemakings and further
explained in our responses to other
comments, EPA’s partial approval and
partial disapproval of the Wyoming
Regional Haze SIP is consistent with the
CAA, the RHR, BART Rule, and EPA
guidance. Our determinations
considered all five factors, not just
visibility improvement.
Comment: Although it is true that
Wyoming did not model the visibility
impact of SNCR, that fact is no
justification for disapproving
Wyoming’s BART. Nothing in the BART
Guidelines or Wyoming’s BART
Modeling Protocol demands modeling
of SNCR, and EPA points to nothing in
either document that requires modeling
of SNCR.
Response: We disagree with this
comment. The BART selection process
requires a comparison between all
technically feasible control options, not
the evaluation of individual control
technologies in isolation. While the
BART Guidelines do not specify the
order in which control options must be
evaluated (e.g., beginning with the most
stringent or beginning with least
stringent control), they do specify that
the CAA factors must be considered for
all options: ‘‘In the final guidelines, we
have decided that States should retain
the discretion to evaluate control
options in whatever order they choose,
so long as the State explains its analysis
of the CAA factors.’’ 70 FR 39130. The
only exceptions are ‘‘. . . if you find
that a BART source has controls already
in place which are the most stringent
controls available . . .’’, or ‘‘. . . . if a
source commits to a BART
determination that consists of the most
stringent controls available . . .’’ 70 FR
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Frm 00092
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39165. In these situations, it is not
necessary to complete an analysis of all
five BART factors. Therefore, because
neither of these criteria was met, the
State was required to perform an
analysis of all five BART factors for all
technically feasible control options. As
such, the State’s failure to consider the
visibility impacts of SNCR did in fact
serve as appropriate grounds for EPA’s
disapproval of Wyoming’s BART
determination.
Comment: EPA modeling shows no
significant visibility improvement from
SNCR and without a significant
improvement there can be no
justification for disapproving the State’s
BART for Laramie River Station, and, to
the contrary, EPA’s modeling supports
Wyoming’s rejection of SNCR and
choice of LNB/OFA because SNCR
provides negligible visibility
improvement.
Response: We have required new
LNBs with OFA and SCR for the
Laramie River Station, not new LNBs
with OFA and SNCR, which is the
control option addressed by the
commenter. Accordingly, we do not find
that the comment is relevant to our
action. Our revised modeling shows that
the visibility benefit of new LNBs with
OFA and SCR for Laramie River Units
1–3 is 0.57 deciviews, 0.53 deciviews,
and 0.52 deciviews, respectively. We
continue to find that the visibility
benefit, when taking into consideration
the remaining BART factors, justifies
installation of new LNBs with OFA and
SCR.
Comment: Basin Electric submitted
results based on more accurate
modeling than EPA, which show that
actual visibility improvement from
SNCR would be substantially lower than
assumed by EPA. There is no
justification for disapproving
Wyoming’s BART based on a modeled
visibility improvement that is such a
small fraction of what is humanly
perceptible.
Response: As described in response to
other comments, we agree that the
original modeling protocol adopted by
the State was inconsistent with the
BART Guidelines, IWAQM Phase 2
report and newly available ambient
monitoring data, and in our revised
modeling we adopted several of the
changes recommended by this
commenter, including the use of lower
background ammonia concentration, a
correction for ammonia limiting
conditions for multiple units located at
a single BART source, and the use of
Method 8 for the evaluation of visibility
impairment. However, even using these
model options, we still found significant
visibility impacts for SCR control at
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Laramie River. Our results are generally
consistent with the modeling results
submitted by the commenter which also
show significant impacts. As described
in another response, while the visibility
benefits at each of these units
individually are less than what is
generally considered perceptible (1
deciview), they are not so low as to
preclude selection of the associated
controls without any consideration of
the remaining BART factors. The BART
Guidelines are clear that States should
consider visibility impacts that are less
than perceptible because these sources
may still contribute to cumulative
visibility impairment.
Comment: EPA did not assert a failure
to model NOX impacts separately was a
flaw in the Laramie River Station
modeling, although EPA did identify
this as a flaw in PacifiCorp modeling.
Response: We agree that the State
evaluated NOX impacts separately for
the control technologies that the State
included in its modeling, however, the
State did not evaluate SNCR. The other
deficiencies in the State’s visibility
analysis, including the failure to
consider the visibility impacts of SNCR,
were appropriate grounds to disapprove
the State’s BART determination.
Comment: The Wyoming modeling
did in fact isolate the impact on
visibility for NOX control alternatives.
Wyoming held SO2 and PM emissions
constant at baseline levels while
modeling varying NOX emission rates
for each of the NOX control options.
Response: We agree with this
comment. Nonetheless, as stated above,
the other deficiencies in the State’s
visibility analysis, which were
inconsistent with the BART Guidelines,
including the failure to consider the
visibility impacts of SNCR, were
appropriate grounds to disapprove the
State’s BART determination.
Comment: EPA claims that Wyoming
modeled the wrong emission rates. EPA
notes that in its cost analysis it
calculated a new removal efficiency for
NOX control options that was different
than the removal efficiency calculated
by Wyoming, and claims that visibility
modeling should have used the EPA
efficiencies. However, EPA does not
explain how modeling with the different
removal efficiencies conflicts with the
BART Guidelines or the CAA. As to
SNCR, EPA argues that the State
assumed a higher removal efficiency
and thus, paradoxically, modeling with
the State’s removal assumption would
yield greater visibility improvement
than modeling with EPA’s values. No
such modeling was done, however. The
State did no modeling for SNCR, so the
State’s removal efficiency was never
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modeled. It is an enigma how EPA can
disagree with modeling with the
different SNCR removal values when
such modeling was never performed.
Response: We disagree with this
comment. The BART Guidelines are
clear on how removal efficiencies
should be considered in the visibility
evaluation: ‘‘Post-control emission rates
are calculated as a percentage of precontrol emission rates. For example, if
the 24-hr pre-control emission rate is
100 lb/hr of SO2, then the post control
rate is 5 lb/hr if the control efficiency
being evaluated is 95 percent.’’ 70 FR
39170. Therefore, because the control
efficiencies assumed by the State
differed from those found by the EPA,
they affected the calculation of postcontrol emission rates for modeling
purposes (and thereby the consideration
of visibility impacts).
In regard to SNCR, as conceded by the
commenter, the State did not provide
the visibility impacts associated with
the control option. As discussed
elsewhere, failure to assess the visibility
impacts of a technically feasible control
option is in clear conflict with the
requirements of the CAA and BART
Guidelines. This failure alone,
regardless of the control efficiency
assumed for SNCR, was sufficient
grounds for us to reject the State’s BART
determination. Moreover, the incorrect
removal efficiency for SNCR assumed
by the State adversely affected their
analysis of cost of compliance, another
statutorily required BART factor.
To put it simply, the State failed in
the first instance by not considering the
visibility improvement of SNCR as
required by the CAA and BART
Guidelines. When EPA corrected this
deficiency by performing the modeling
ourselves, it was necessary for us to
correct the removal efficiency of SNCR
(as discussed in response to other
comments).
Comment: The State assumed that
SCR would reduce NOX emissions from
0.21 lb/MMBtu to 0.07 lb/MMBtu—a
reduction of 0.14 lb/MMBtu. EPA
assumes SCR would reduce NOX
emissions from 0.19 lb/MMBtu to 0.05
lb/MMBtu, a reduction of the same 0.14
lb/MMBtu. All other things being held
constant, the 0.14 lb/MMBtu reduction
will in both cases yield an identical
reduction in the visibility impairing
concentration of nitrate particulate in a
Class I area.
Response: We disagree with this
comment. The CALPUFF model
simulations estimate the visibility
impairment attributed to the emissions
in each control scenario, not the relative
reduction in different control scenarios.
Therefore, an emissions rate of 0.07 lb/
PO 00000
Frm 00093
Fmt 4701
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5123
MMBtu will have 40% greater total
emissions and a larger visibility impact
than an emissions rate of 0.05 lb/
MMBtu.
Comment: EPA argues that Wyoming
should have used a baseline of the
maximum 24-hour average NOX
emission rate during the baseline years
of 2001–2003, and instead used an
annual average baseline rate. The BART
Guidelines do not mandate the use of
the 24-hour maximum but, rather,
‘‘recommend that the State use the
highest 24-hour average actual emission
rate’’ and that the states should have
flexibility when evaluating the fifth
statutory factor. The BART Guidelines
by their express terms authorize states
to use baseline emissions other than the
24-hour maximum rate. Use of the 24hour maximum baseline is not
mandatory, and not using that baseline
is not a failure to comply with any
requirement in the Guidelines. EPA
itself used annual average pre-control
and post-control emission rates to
model visibility impacts in its Nevada
FIP rulemaking.
Response: We disagree with this
comment. As stated in the preamble to
the BART Guidelines, ‘‘the emissions
estimates used in the [visibility] models
are intended to reflect steady-state
operating conditions during periods of
high capacity utilization.’’ 70 FR 39120.
As such, the BART Guidelines
recommend excluding emissions during
periods of start-up, shutdown, or
malfunction or estimating visibility
impacts based on a source’s allowable
emissions as this could inflate the
visibility impacts of a source. Rather, for
sources such as power plants where
States have information on a source’s
daily emissions, the BART Guidelines
explains that an emission rate based on
a source’s maximum actual emissions
over a 24-hour period is an appropriate
gauge of a source’s potential impact as
it ensures that peak emission conditions
are reflected but would be unlikely to
lead to an overestimation of a source’s
potential impacts. Id. The BART
Guidelines state that in developing a
modeling protocol, States should ‘‘[u]se
the 24-hour average actual emission rate
from the highest emitting day of the
meteorological period modeled (for the
pre-control scenario).’’ Id. and 70 FR
39170.
Wyoming did not do this. Instead, in
assessing the improvement in visibility
associated with the use of controls in its
BART determinations, Wyoming used
the visibility modeling performed by
PacifiCorp and Basin Electric for their
facilities. Although these companies
used very different approaches to
estimating the baseline emission rate—
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neither of which used the 24-hour
average actual emission rate—the State
accepted the visibility modeling done
by both and submitted the results in the
Wyoming SIP. Even if the commenter
were correct that the approach in the
BART Guidelines is only recommended,
the commenter has not provided any
explanation as to why the disparate
approaches used in the Wyoming SIP
were appropriate for estimating the
degree of visibility improvement
associated with controls. Wyoming
similarly provided no explanation as to
why the varying approaches adopted by
Basin Electric and PacifiCorp were
appropriate for assessing visibility
improvement. Moreover, the commenter
has not established that the baseline
emission rates used by Wyoming would
accurately reflect visibility impacts
associated with steady-state operating
conditions during periods of high
capacity utilization. Obviously, baseline
emission rates reflecting periods of
relatively lower capacity utilization
would tend to underestimate peak
visibility impacts. Consider for example
the baseline emission rate used for
Laramie River Unit 1. There, the State
used a daily emission rate equating to
6,320 tons per year,123 while, based on
actual emissions data, the EPA used a
daily rate equating to 8,786 tons per
year.124 Thus, the rate used by the State
reflects a period of considerably lower
capacity utilization that would therefore
tend to underestimate peak impacts.
Regarding the emissions rates used in
the Nevada regional haze SIP, the State
did not use the 24-hour average of
actual emissions from the highest
emitting day in its BART determination
for Reid Gardner Generating Station. 77
FR 50936, 50944 (Aug. 23, 2012). As
part of its review of the Nevada SIP,
EPA performed new visibility modeling.
In that modeling exercise, EPA used
Nevada’s emission rates based on
annual averages. Please refer to a related
comment and response in the final
action for that rule for a full discussion.
See 77 FR 50944). Following our review
of comments in that rulemaking—
including comments that we should
have used the Guidelines maximum 24hour average of emissions in our
visibility modeling—we scaled our
estimates of the visibility impacts of
controls based on the source’s emissions
using the Guidelines maximum 24-hour
average. We took these scaled visibility
123 Wyoming Department of Environmental
Quality Air Quality Division BART Application
Analysis AP–6047, Table 16, May 28, 2009.
124 Air Quality Modeling Protocol: Wyoming
Regional Haze Federal Implementation Plan, U.S.
EPA, Table B.9, January, 2014.
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impacts into account in our final action.
Id. at 50945.
Comment: EPA did not use the 24hour maximum rate for the modeling it
performed in 2012. As noted in Section
VIII.C, it used the same baseline
emission rates used by the State. EPA–
R08–OAR–2012–0026–0037. EPA did
not find the State’s approach was a
violation of the BART Guidelines or was
a reason to disapprove the State’s
modeling or BART determination.
Having sanctioned the use of a different
baseline then, EPA may not now claim
it violates the BART Guidelines or a
ground for disapproving the State’s
modeling or BART determination.
Response: We agree that we did not
use the 24-hour maximum [actual]
emission rates for modeling purposes in
our original proposed rule published in
2012. However, we did not finalize that
rule, at least in part, for the very reason
that the baseline emission rates
calculated by Wyoming, and
subsequently used by EPA in the 2012
proposed rule, were inconsistent with
the BART Guidelines. As we never
finalized the original rule, we disagree
with the commenter’s suggestion that
we somehow sanctioned Wyoming’s
approach. A proposed rule does not
represent final agency action.
Comment: The maximum
improvement modeled by EPA that
would be achieved at any Class I area by
adding SCR to the existing new LNB
plus OFA is 0.5 delta deciview. This is
below the 1.0 delta deciview level often
cited as the lowest level of change that
is humanly perceptible. For EPA to
propose disapproval of the State’s BART
based on an imperceptible improvement
is to propose disapproval based on a
nonmaterial factor.
Response: We disagree that the
visibility improvements for Laramie
River or Jim Bridger are de minimis or
too small to just justify the expense of
requiring controls. As discussed in
response to another comment, the BART
Guidelines are clear that it is not
necessary for the visibility improvement
of a particular control option to be
above the perceptible threshold. The
regional haze program is premised on
the fact that numerous sources are
contributing to visibility impairment
and numerous sources will need to
reduce emissions in order to improve
visibility. We continue to find that this
level of improvement, when considered
along with the other statutory factors,
justifies the selected BART controls.
Comment: The commenter states that
EPA’s modeled visibility improvement
overstates the improvement that would
actually be achieved. The commenter
submitted new modeling showing that
PO 00000
Frm 00094
Fmt 4701
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the visibility improvement from further
reductions of NOX emissions would be
much smaller than that predicted by
EPA. AECOM corrected four of the flaws
in EPA’s modeling and re-ran
CALPUFF. The commenter submitted
refined modeling with four adjustments:
1. The use of seasonal background
ammonia concentrations; 2. Modeling of
all units together with correction for
ammonia limited conditions; 3. Use of
a post-control emission rate of 0.07 lb/
MMBtu, consistent with EPA’s proposed
emission limit; and 4. The use of
CALPOST Method 8. AECOM’s revised
modeling was identical to EPA’s in all
other respects. The refined modeling
predicted that the incremental visibility
benefit of SCR at each of Laramie River
Units 1, 2 and 3 would range between
0.20–0.24 delta deciview at either
Badlands or Wind Cave National Park.
The actual visibility improvement of
SCR would be even less than predicted
by the refined modeling because
CALPUFF is known to substantially
overstate nitrate haze.
Response: We agree that our proposed
modeling was inconsistent with the
BART Guidelines, IWAQM Phase 2
report and monitored data, and in our
revised final modeling we adopted
several of the changes recommended by
this commenter, including the use of
lower background ammonia
concentration, a correction for ammonia
limiting conditions for multiple units
located at a single BART source, and the
use of Method 8 for the evaluation of
visibility impairment. However, even
using these less conservative model
options, we still found significant
visibility impacts for SCR control at the
Basin Electric Laramie River EGUs. We
did not use the seasonal background
ammonia concentration proposed by the
commenter because we did not have
sufficient ambient monitoring data to
determine the seasonal background
concentrations in eastern Wyoming.
Comment: The commenter states that
nitrate haze occurs primarily in the
winter when few visitors are present in
Class I areas. During the peak summer
visitation period, the impact of wildfires
would overwhelm any marginal
visibility improvement that might be
achieved by SCR. The commenter cites
an EPA report that stated ‘‘[A] all else
being equal, impairment from
anthropogenic sources is considerably
more objectionable during times of the
year with greatest visitor attendance
(e.g., summer). Visibility objectives
might, therefore, be stated in terms of
acceptable frequency distributions of
visibility (e.g., contrast) over the course
of a year.’’ Source: Report to Congress
under CAA Section 169A(a)(3). The
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commenter states that these factors
further support Wyoming’s decision to
reject SCR and SNCR as BART. These
technologies would not improve
visibility on the worst haze days
because Laramie River doesn’t
contribute to haze on those days, and
any slight visibility improvement would
occur in the winter season when few
visitors enter the Class I areas.
Wyoming’s decision to reject SCR as
BART is therefore reasonable and
complies with the CAA.
Response: As discussed in response to
another comment, EPA agrees that
nitrate impacts are more dominant in
the winter. Nonetheless, daily nitrate
impacts from April through October are
not trivial. EPA also agrees that the
BART Guidelines allow states to
consider the timing of impacts in
addition to other factors related to
visibility impairment. However, states
are not required to do so, and EPA is not
required to substitute a source’s desired
exercise of discretion for that of the
states. Furthermore, when promulgating
a FIP, EPA stands in the shoes of the
state. In that capacity, EPA is not
required to consider the seasonality of
impacts and has chosen not to do so
here. Taking into account visitation
contradicts the goal of the regional haze
rule of improving visibility on the 20
percent best and worst days. Indeed,
EPA believes that the experiences of
visitors who come to Class I areas
during periods other than the peak
visitation season are important and
should not be discounted.
Comment: We received comments
that our FIP was not warranted because
the cause of visibility impairment
during the times of peak visitation was
wildfires and thus does not justify the
control of NOX from stationary sources.
Response: See response above.
Comment: Ammonia levels at the
altitude of the plume would be lower
than the reported surface level ammonia
concentrations, so less ammonia would
be available to form visibility-impairing
nitrate.
Response: We disagree that there is
compelling evidence that background
ammonia levels are significantly
different at the altitude of the plume
compared to the surface. While there are
limited studies showing vertical
gradients of ammonia in the
troposphere,125 these studies do not
show a strong gradient within the
planetary boundary layer where the
plume is typically located. Moreover, as
discussed in the response to another
125 Levine et al., (1980) The Vertical Distribution
of Tropospheric Ammonia, Geophys. Res. Letters,
vol. 7, No. 5, 17–32.
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comment, it is necessary to evaluate the
combined concentrations of gas
ammonia and particulate ammonium to
estimate the background ammonia level,
so vertical gradients in measured
ammonia alone are not sufficient to
specify the vertical gradient in
background ammonia. It is possible that
decreasing temperature with altitude
could affect the thermodynamic
equilibrium between gas ammonia and
particulate ammonium and that this
could contribute to observed vertical
gradients in ammonia. It is also possible
that dry deposition of ammonia at the
surface could create a negative vertical
gradient in ammonia near the surface.
We recognize that there are limited
measurement studies available for total
gas ammonia and particulate
ammonium, and as a result there is
uncertainty in the estimate of
background ammonia. Given this
uncertainty, we believe it is appropriate
to rely on measurement studies of total
gas ammonia and particulate
ammonium when available and reliable
as explained elsewhere in this
document (along with the IWAQM
Phase 2 report default values), and to
rely on the IWAQM Phase 2 report
where monitoring data are not available.
Comment: The commenter states that
inventories show very low ammonia
concentrations in the corridors between
Laramie River Station and the relevant
Class I areas.
Response: We disagree with the
commenter’s assertions. We note that
there is large uncertainty in estimates of
ammonia emissions inventories that are
based on source activity data and
emissions factors. Moreover, even when
more certain estimates of ammonia
emissions are available, it is not
possible to estimate ambient ammonia
concentrations based on emissions
inventory data alone. An estimate of
ambient ammonia levels would require
an evaluation of modeled emissions
data and the effects of transport,
dispersion and removal of ambient
ammonia. Direct measurements of
ambient concentrations of gas ammonia
and particulate ammonium provide a
more reliable estimate of background
ammonia than do model simulations of
the emissions, transport, dispersion and
removal of ammonia.
Comment: The commenter states that
reliable ammonia measurements from
the IMPROVE monitor located in the
Wind Cave National Park were
published in September 2012. Chen et
al, available at AECOM Report. This
monitor provides actual ground level
ammonia data that is representative of
the Class I areas that are relevant to
Laramie River Station. AECOM Report
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5125
at 4. EPA has given no explanation for
its assumption of a constant 2.0 ppb
background concentration in this case.
Response: We evaluated the ammonia
and ammonium monitoring data
submitted by the commenter in Exhibit
6, which is an extended abstract
presented at the 2010 conference in
Whitefish, MT.126 The data are from a
pilot study conducted from April 2011
to January 2012 designed to measure
total NHX as the sum of ammonia and
particulate ammonium at 9 IMPROVE
sites. The pilot study includes data for
IMPROVE monitoring sites at Wind
Cave and Rocky Mountain National
Park, which are Class I areas for which
we evaluated visibility impacts in this
action. We note that the pilot study data
are for less than one full year and are
plotted in Figure 1 of the report as
monthly average concentrations. The
measured values of NHX are not
reported, but the plot does show
seasonal variation in NHX
concentrations, as expected, with higher
NHX concentrations in summer and
lower concentrations in winter. Annual
average NHX concentrations cannot be
estimated from the plot itself, but they
appear to be approximately consistent
with the default IWAQM ammonia
background concentration of 0.5 ppb for
forested areas. Given that both the
Rocky Mountain and Wind Cave Class
I areas have significant forest cover, the
measurements in the pilot study appear
to be consistent with the IWAQM Phase
2 report.
Measurements of NHx are not reported
for Badlands National Park, which is a
mix of bare rock and mixed-grass prairie
ecosystems. Based on the IWAQM Phase
2 report, default background ammonia
concentrations in the range of 1 to 10
ppb at 20 degrees Celsius would be
appropriate for this region. We reviewed
the ambient ammonia monitoring data
on which the IWAQM Phase 2 report
was based, and the data for grasslands
were largely based on measurements at
Pawnee National Grassland, where
average ammonia levels in summer were
10 ppb. Because the Pawnee National
Grassland is located close to large
agricultural and livestock ammonia
sources in eastern Colorado, it is
uncertain if the same ammonia levels
would be appropriate for the more
Badlands area. Therefore, we selected a
background ammonia concentration of 1
ppb for CALPUFF modeling of BART
sources that impact the Wind Cave and
Badlands Class I areas.
126 Chen et al., A Pilot Monitoring Study of
Atmospheric NHX at Selected IMPROVE sites
AWMA Aerosol and Atmospheric Optics, Visibility
& Air Pollution Conference, September 24–28, 2012,
Whitefish, MT.
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Comment: The commenter states that
if EPA uses the maximum 24-hour NOX
emissions rate when modeling baseline
visibility impacts, it should also use the
maximum 24-hour SO2 and PM10
emissions rates for the baseline. NOX
competes with SO2 for ammonia to
make either ammonium nitrate or
ammonium sulfate. Setting the SO2
baseline rate at a low concentration
relative to NOX skews the model to
predict the formation of more
ammonium nitrate and less ammonium
sulfate. This magnifies the modeled
benefits of reducing NOX emissions.
Response: We agree that we did not
use the maximum [actual] 24-hour
emission rates for SO2 and PM10 as we
did for NOX. However, we have not
found based on our analysis, and the
commenter has not established, that
doing so had any material impact on the
modeled benefits associated with NOX
controls. The BART sources in
Wyoming that are covered in this action
are subject-to-BART only for NOX and
PM. In addition, we considered
comments on, but did not question the
validity of the State’s BART analyses for
PM. In fact, as explained in detail
elsewhere in this document, with
respect to the State’s PM BART
determinations, the State’s SIP and
existing information was adequate to
find that the PM BART determinations
were reasonable. Accordingly, the
purpose of our modeling effort was to
identify the visibility improvement
associated with NOX controls, not SO2
or PM controls. And so, in evaluating
the visibility of NOX controls, we held
the SO2 and PM emissions constant at
the rate associated with the ‘‘committed
controls’’ identified by the State.
Therefore, even if there was a
discernible impact on the modeled
visibility benefit of NOX controls related
to our treatment of modeled emission
rates for SO2 and PM, it would be
common to all of the modeled NOX
control scenarios and would not have
favored one control option over another.
Comment: The visibility improvement
from SCR will be much less than EPA
claims. The modeling preformed by
AECOM and Wyoming produced similar
results, and both predicted much less
visibility improvement than EPA.
Response: The modeling performed
by Wyoming used the 2 ppb background
concentration that was established in
the State’s protocol, and this resulted in
model visibility impacts that were
significantly greater than those
estimated by AECOM in its modeling
using lower, seasonally varying
background ammonia concentrations.
The ammonia concentrations in ppb
used in the AECOM modeling for the
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months of January December were as
follows: 0.3, 0.9. 0.9, 1.0, 1.0, 2.0, 2.0,
1.0, 0.8, 0.8, 0.6, and 0.3. We note that
our modeling results in our original
proposal also used the State’s protocol,
and our model results were identical to
the State’s modeling results for the
emissions scenarios that both the State
and EPA evaluated. The EPA modeling
results in our revised proposal showed
larger visibility impacts because we
corrected the baseline emissions rates to
make the emissions consistent with the
BART Guidance. In the new modeling
results that we performed using our
revised final EPA Protocol and included
in this action, we used a model
configuration that is generally
consistent with modeling submitted by
the commenter. The revisions to the
protocol include reduced background
ammonia, correction for ammonia
limiting conditions, updated regulatory
versions of the model, and the use of
Method 8. The commenter did not
submit model results for all emissions
scenarios in a format that can be directly
compared to our tabulated model
results, but our revised model results in
this action appear to be generally
consistent with the commenter’s model
results, and these results do show that
SCR at Basin Electric Laramie River has
appreciable visibility benefit at the
Wind Cave and Badlands Class I areas.
Comment: The commenter states that
the version of CALPUFF used by
Wyoming and EPA (version 5.711a)
relies on simplified chemistry
algorithms that overstate nitrate
formation and overpredict visibility
impacts, and that EPA acknowledges
that ‘‘the simplified chemistry in the
[CALPUFF] model tends to magnify the
actual visibility effects of [a] source.’’ 70
FR 39121. Papers by Morris et al. and
Karamchandani et al. show that
CALPUFF chemistry overpredicts
nitrates by a factor of 2-to-4 times in
winter.
Response: As described in responses
to other comments and in our modeling
protocol, EPA used the currently
approved CALPUFF version 5.8 for
modeling used in this action. EPA has
acknowledged in the BART Guidelines
that there is uncertainty in the
CALPUFF modeled visibility impacts.
EPA recognized the uncertainty in the
CALPUFF modeling results when EPA
made the decision, in the final BART
Guidelines, to recommend that the
model be used to estimate the 98th
percentile visibility impairment rather
than the highest daily impact value.
While recognizing the limitations of the
CALPUFF model in the BART
Guidelines Preamble, EPA concluded
that, for the specific purposes of the
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Regional Haze Rule’s BART provisions,
CALPUFF is sufficiently reliable to
inform the decision making process.
Comment: The commenter states that
a study by the CDPHE showed model
results for nitrates will be skewed high
by assuming higher than actual
background levels of ammonia.
Response: The CDPHE completed a
CALPUFF model sensitivity study that
evaluated the effect of the background
ammonia concentration on model
predictions for ammonium nitrate and
sulfate. The CDPHE found that
CALPUFF model predicted nitrate was
insensitive to variations in background
concentrations greater than 10 ppb and
became progressively more sensitive to
background ammonia as it was reduced
from 10 to 0 ppb.127 We note that
CDPHE performed a sensitivity study
but did not evaluate model performance
and did not identify any particular case
in which model performance was
skewed by the use of inappropriate
background ammonia concentrations.
The conclusions of the CDPHE study are
fully consistent with the IWAQM Phase
2 report, which also recognized that
accurate specification of background
ammonia ‘‘is critical to the accurate
estimation of particulate nitrate
concentrations.’’ 128
Comment: The commenter cites
several presentations and studies that
document flaws in CALPUFF’s sulfate
and nitrate chemistry: (1) It is out of
date, overly simplistic, and inaccurate;
(2) CALPUFF greatly overstated sulfate
and nitrate in winter, overestimating
visibility impacts by 100–1000% in
many cases; and (3) that the model
understated sulfate in summer; and that
nitrate predictions were particularly
inaccurate, overstated, and unreliable.
Response: EPA recognized the
uncertainty in the CALPUFF model
when EPA made the decision, in the
final BART Guidelines, to recommend
that the model be used to estimate the
98th percentile visibility impairment
rather than the highest daily impact
value. While recognizing the limitations
of the CALPUFF model in the BART
Guidelines, EPA concluded that, for the
specific purposes of the RHR’s BART
provisions, CALPUFF is sufficiently
reliable to inform the decision making
process.
Comment: NOX emissions control has
little visibility benefit during summer
when visibility impairment is
dominated by wildfires.
Response: EPA agrees that nitrate
impacts are more dominant in the
winter. The CALPUFF model results are
127 CDPHE,
Ibid.
page 14 and page 21
128 IWAQM,
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consistent with these observations, with
the largest modeled visibility
improvements occurring from late fall to
early spring. NOX emissions are
precursors to ammonium nitrate, and
high concentrations of ammonium are
typically observed from late fall to early
spring when cold temperatures and high
relative humidity results in
thermodynamic conditions that favor
the formation of ammonium nitrate.
Observed ammonium nitrate
concentrations are typically low during
summer because warm temperatures
result in thermodynamic conditions that
are not favorable to the formation of
ammonium nitrate. Nonetheless, there
may be higher nitrate concentrations on
colder days during this period.
Comment: EPA’s visibility-benefits
analysis still is constrained in the reproposed Wyoming haze plan because
EPA has not identified the visibility
benefits from BART controls across all
of the Class I areas affected by hazecausing pollutants from Wyoming
sources. Wyoming EGUs impact
visibility over at least 18 Class I areas.
While EPA’s own visibility modeling
fully supports determinations that SCR
is BART for all Wyoming EGUs, the
visibility benefits of SCR across all
affected Class I areas are cumulatively
significant and, if the RHR’s
fundamental purpose is to be fulfilled,
they must not be ignored.
Response: EPA disagrees with this
comment. The commenter’s number of
‘‘at least 18 Class I areas’’ is derived by
including Class I areas that are more
than 300 km from BART sources. EPA
disagrees that these Class I areas should
be included in the visibility analysis.
The IWAQM Phase 2 report reviewed
model performance evaluations of
CALPUFF as a function of distance from
the source and concluded that:’’Based
on the tracer comparison results
presented in Section 4.6, it appears that
CALPUFF provides reasonable
correspondence with observations for
transport distances of over 100 km. Most
of these comparisons involved
concentration values averaged over 5 to
12 hours. The CAPTEX comparisons,
which involved comparisons at
receptors that were 300 km to 1000 km
from the release, suggest that CALPUFF
can overestimate surface concentrations
by a factor of 3 to 4. Use of the puff
splitting option in CALPUFF might have
improved these comparisons, but there
are serious conceptual concerns with
the use of puff dispersion for very longrange transport (300 km and beyond).
As the puffs enlarge due to dispersion,
it becomes problematic to characterize
the transport by a single wind vector, as
significant wind direction shear may
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well exist over the puff dimensions.
With the above thoughts in mind,
IWAQM recommends use of CALPUFF
for transport distances of order 200 km
and less. Use of CALPUFF for
characterizing transport beyond 200 to
300 km should be done cautiously with
an awareness of the likely problems
involved.’’ 129 We present additional
discussion of this issue in our response
to the following comment.
Comment: EPA arbitrarily failed to
model visibility impacts of the various
control options at all affected Class I
areas, including those that are beyond
300 km from the source. EPA recently
responded to a similar comment in its
final action promulgating the Montana
Regional Haze FIP, 77 FR 57864, for the
first time supporting its truncated
modeling by referencing a nowdiscredited 1998 report regarding
CALPUFF performance. Because EPA
raised this issue only after the close of
the public comment period on its
Wyoming regional haze action, EPA
should consider the Conservation
Organizations’ response. See 42 U.S.C.
7607(d)(4)(B)(i).
In its response to public comments on
the Montana FIP, EPA stated, ‘‘The
Interagency Workgroup on Air Quality
Modeling (IWAQM) Phase 2 report
(EPA, 1998) reviewed model
performance evaluations of CALPUFF as
a function of distance from the source
and concluded that: . . .[u]se of
CALPUFF for characterizing transport
beyond 200 to 300 km should be done
cautiously with an awareness of the
likely problems involved.’’ 77 FR
57867–68. EPA then concludes,
‘‘[t]herefore, given that the IWAQM
guidance provides for the use of the
CALPUFF model at receptor distances
of up to 200 to 300 km, and given that
EPA has already addressed uncertainty
in the CALPUFF model, we believe it is
reasonable to use CALPUFF to evaluate
visibility impacts up to 300 km.’’ Id. at
57868.
We agree that CALPUFF is reliable at
distances of 300 km. However, EPA’s
use of the IWAQM Phase 2 report to
support its decision to exclude
modeling at distances beyond 300 km is
arbitrary. First, changes to CALPUFF
since 1998 may correct problems
identified in the IWAQM Phase 2 report
with modeling accuracy in the 200–
1,000 km range. Second, a more recent
study prepared for EPA called into
question the conclusions of the IWAQM
Phase 2 report upon which EPA relies.
See Long Range Transport Models Using
Tracer Field Experiment Data (May
2012) (EPA Contract No: EP–D–07–102,
129 IWAQM,
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Work Assignment No: 4–06). The May
2012 study concluded that ‘‘The
inability of most (∼90%) of the current
study’s CALPUFF sensitivity tests to
reproduce the 1998 EPA study tracer
test residence time on the 600 km
receptor arc is a cause for concern.’’ Not
only were the authors of the May 2012
study unable to reproduce the 1998
study’s findings that CALPUFF
overestimated pollutant concentrations
at distances of 600 km, the 2012 study
concluded that CALPUFF actually
underestimates average pollutant
concentrations at 600 km. Accordingly,
reliance on CALPUFF at long distances
would result in conservative estimates
of visibility impacts. It is not
appropriate to assume, as EPA
effectively did in its Wyoming proposal,
that such impacts are non-existent.
EPA’s failure to model and consider
visibility impacts at all affected Class I
areas, including those beyond 300 km,
is not supported.
Because the RHR, and SIPs and FIPs
promulgated to implement it, are to
fulfill CAA requirements to mitigate and
ultimately eliminate anthropogenic
sources of haze pollution at all Class I
national parks and wilderness areas, it
is imperative that states and EPA use
models to completely and accurately
depict the visibility impact of a source
to the region’s Class I areas as well as
projected benefits from BART. In this
regard, the conclusion of the May 2012
study that CALPUFF reliably (if
conservatively) identifies visibility
impacts to Class I areas beyond those
previously evaluated are critical, and
directs EPA to supplement the
incomplete analysis presented in its
proposed action on the Wyoming
Regional Haze plan with additional
modeling, or consider the more
complete modeling submitted by the
conservation organizations with their
August 2, 2012 comments.
Response: EPA disagrees with the
commenter’s assertion that changes to
CALPUFF now support modeling at
distances greater than 300 km. The
commenter cited a May 2012 technical
evaluation (Documentation of the
Evaluation of CALPUFF and Other Long
Range Transport Models Using Tracer
Field Experiment Data 130) that
evaluates several long range transport
models based on several tracer studies.
The report cited by the commenter does
not refute the IWAQM Phase 2 report
which states that ‘‘IWAQM recommends
use of CALPUFF for transport distances
of order 200 km and less. Use of
CALPUFF for characterizing transport
130 https://www.epa.gov/scram001/reports/EPA454-R-12-003.pdf.
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beyond 200 to 300 km should be done
cautiously with an awareness of the
likely problems involved.’’ 131 In fact,
the May 2012 report further
‘‘emphasizes the need for a standardized
set of options for regulatory CALPUFF
modeling.’’ 132 Given these findings,
EPA does not agree, as the commenter
asserts, that it must consider CALPUFF
modeling results from Federal Class I
areas beyond 300 km. EPA therefore
believes that the results of CALPUFF
modeling beyond 300 km of the source
should be evaluated in light of the
limitations discussed in the two
guidance documents cited above.
Finally, we disagree that there is any
notice issue with respect to the
commenter’s allegations that EPA
referenced the 1998 IWAQM study for
the first time in our response to
comments in our Montana FIP action.
As quoted above, the BART guidelines
specifically reference the 1998 IWAQM
study with respect to CALPUFF settings.
Comment: EPA modeled visibility
benefits at four Class I areas, and
demonstrated visibility improvement
due to SCR that approximately doubled
the improvement afforded by SNCR at
every Class I area modeled. 78 FR
34775–34776. EPA properly took
account of the cumulative visibility
improvement across all four modeled
Class I areas for each unit, id. at 34776,
but in fact, as the Conservation
Organizations commented previously,
see 8/2/2012 Conservation Organization
Comments, SCR affords visibility
benefits across at least six Class I areas.
Thus, the cumulative visibility benefits
are even greater than found by EPA, and
further support a determination that
SCR is BART for Laramie River Station
Units 1–3.
Response: We disagree that we should
have evaluated visibility impacts at all
of the areas that the commenter
considered in its analysis. The
commenter provided CALPUFF model
results at 18 areas, including areas that
are not mandatory Class I areas, and at
Class I areas at distances greater than
300 km from Laramie River Station. In
our analysis of visibility impacts, we
considered the visibility improvement
at four Class I areas within 300 km of
the Laramie River Station. Therefore,
our modeling analyses did not ignore
the visibility improvement that would
be achieved at areas other than the most
impacted Class I area, and we disagree
with the assertion that we should have
131 https://www.epa.gov/scram001/7thconf/
calpuff/phase2.pdf, page 18.
132 https://www.epa.gov/scram001/reports/EPA454-R-12-003.pdf, page 10.
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evaluated all of the areas that the
commenter considered.
Comment: EPA’s re-proposed
Wyoming haze plan presents a unit-byunit analysis of the visibility benefits of
the installation of various BART control
alternatives at Wyoming EGUs, and
identifies benefits at only a subset of the
affected Class I areas. However, EPA did
not present evidence of the cumulative
visibility benefits that would be enjoyed
by Class I areas from implementation of
all of the BART determinations in its
2013 re-proposal. To assess this
shortcoming, the Conservation
Organizations contracted with Howard
Gebhart to conduct a cumulative
visibility improvement modeling
analysis that compared installation of
the NOX BART determinations found in
EPA’s 2013 re-proposal versus the State
BART determinations found in the
Wyoming Regional Haze SIP. See
Gebhart Report, at 17–24. Mr. Gebhart’s
visibility modeling results show that
installation of the BART determinations
in EPA’s 2013 re-proposal will result in
significant visibility improvement at
numerous Class I areas when compared
to the Wyoming SIP. For example,
installation of the BART determinations
in EPA’s 2013 re-proposal would
consistently result a total deciview
improvement of 1.0 deciview or greater
over the Wyoming SIP at Badlands
National Park, Savage Run Wilderness,
and Wind Cave National Park. In
addition, significant visibility
improvements exceeding 0.5 deciviews
were predicted at Badlands National
Park, Bridger Wilderness, Mount Zirkel
Wilderness, Rawah Wilderness, Rocky
Mountain National Park, Savage Run
Wilderness, and Wind Cave National
Park. In summary, the Conservation
Organizations’ cumulative visibility
improvement modeling analysis
provides further support that significant
visibility benefits can be achieved from
the finalization of the BART
determinations contained in EPA’s 2013
re-proposal. EPA’s 2013 re-proposed
rule advances (without entirely
fulfilling) the goals of the regional haze
program to reduce visibility impairment
using BART during the first regional
haze five-year planning period. In
contrast, the Wyoming Regional Haze
SIP would fall far short of these goals.
Response: First, we note that the
modeling performed by the
Conservation Organizations’ contractor
used the 2 ppb background ammonia
concentration, and did not correct the
model results for ammonia limiting
conditions, and therefore predicts
greater visibility impairment than did
EPA’s revised modeling. EPA provided
information about the visibility
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improvement modeled for different
BART scenarios at multiple Class I areas
within 300 km of each BART source.
EPA primarily relied on the benefits at
the area with the greatest visibility
improvement from controls, but we also
considered the cumulative impacts and
benefits at multiple Class I areas. EPA
agrees that considering cumulative
visibility benefits by aggregating the
expected improvement from over
multiple Class I areas is a useful metric
that can further inform a BART
determination. Such an approach can be
useful, for example, in simplifying a
complex array of visibility impacts,
especially where a source has
significant impacts on multiple Class I
areas.
Comment: EPA’s proposed rule fails
to present the cumulative visibility
benefits of installation of SCR at
Wyoming’s EGUs. Instead, EPA only
presents the visibility benefits for a
single Class I area per source (Wind
Cave National Park for all sources
except the Jim Bridger plant (Mount
Zirkel Wilderness Area)). The
cumulative impact of a source’s
emissions on visibility as well as the
cumulative benefit of emission
reductions is a necessary consideration
as part of the fifth-step in the BART
analysis. The statutory direction and
goal of the regional haze program is to
remedy any existing impairment of
visibility in mandatory Class I areas. 42
U.S.C. 7491(1). The implementing
regulations plainly anticipate the need
to reduce impacts in multiple Class I
areas, including those outside a state’s
borders, and the obligation to assess
what is necessary to do so. 40 CFR
51.308(d)(3). Further, states are required
to establish reasonable progress goals for
each Class I area, not just the one most
impacted by a single source. Id. section
51.308(d)(1). EPA’s own regional haze
guidance document states that a
cumulative visibility benefit analysis is
generally consistent with the CAA. 70
FR 39105, 39107 (we believe that a
State’s decision to use a cumulative
analysis at the eligibility stage is
consistent with the CAA); 40 CFR Part
51, App Y. While the Guidelines also
contemplate and even allow analysis of
only the most impacted Class I area,
such an analysis contradicts the regional
approach towards the restoration of
visibility. Moreover, given the number
of Class I areas impacted by Wyoming
sources, it is illogical and baseless to
fictitiously limit the spectrum of source
impact and emission control benefit.
Based upon the guidance and the
requirements of the CAA, the
cumulative impact of a source’s
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emissions on visibility, as well as the
cumulative benefit of emission
reductions, should be considered as part
of the fifth-step in the BART analysis.
The FLMs, too, have urged EPA Region
8 to consider the cumulative visibility
benefits of requiring stricter controls on
BART-eligible units in Montana. For
example, at a public meeting in Billings,
regarding the Montana Regional Haze
SIP, Valerie Naylor, Superintendent of
Theodore Roosevelt National Park
stated, ‘‘EPA placed too much emphasis
on incremental costs and incremental
benefits, while eliminating
consideration of cumulative benefits
that would be realized in the numerous
Class I National Parks, National Wildlife
Refuges, and Wilderness Areas
impacted by Colstrip.’’ The National
Park Service (NPS) has consistently
requested that cumulative visibility
benefit analyses be conducted in other
regional haze determinations. In
addition, EPA must consider the
cumulative visibility benefit of BART
controls on multiple units of a single
source. EPA’s BART guidelines make
clear that states must consider
emissions from an entire source in
determining whether a source is subject
to BART, and further clarify that
multiple units at a single utility
constitute a single source. 40 CFR Part
51, App Y, sect. II.A.
The Conservation Organizations
retained Air Resource Specialists, Inc.
(ARS) to evaluate the cumulative
visibility impact of NOX BART controls,
and found that the cumulative benefit of
SCR at all Wyoming BART-subject EGUs
is very significant. In conducting its
supplementary modeling, ARS used an
SCR-controlled NOX emission rate to
0.05 lb/MMBtu to reflect the level of
control achievable with SCR and
recalculated baseline emissions to
comply with the BART guidelines, as
described in sections I.A.2 and I.C.
Otherwise, ARS employed the same
assumptions used by EPA in its
analysis.
ARS’s visibility modeling addresses
impacts to 18 Class I areas, including
Savage Run Wilderness Area (which is
not a mandatory Class I area but is
managed as such by Wyoming). The
ARS report addresses the cumulative
benefit of installation of SCR at multiple
units at a single power plant location
(ex. the cumulative benefits of
installation of SCR at all four Bridger
units). The ARS Report also calculates
the cumulative visibility benefit of
installation of SCR on all BART units in
Wyoming. Id. It should not be assumed
that ARS’s results document the highest
impacts. Rather, they are presented to
demonstrate widespread and far-
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reaching visibility impacts and
improvements that can be achieved
through the use of SCR.
The cumulative visibility benefit from
installation of SCR on all BART units in
Wyoming is significant. The application
of SCR control on Wyoming’s subject-toBART emission units is predicted to
improve worst-case visibility
impairment by up to 8 deciviews at the
Savage Run Class I area, with 4
deciviews of improvement or better at
six Class I areas. ARS Report, Table 3–
13. For the 98th percentile day, the
improvement after SCR emissions
control at all Wyoming BART-subject
EGUs is as high as 3.5 deciviews at
Wind Cave National Park. Id. At least
six different Class I areas show
improvement of 3 deciviews or more
based on the 98th percentile day after
SCR emissions control at all Wyoming
BART-subject EGUs. Id.
SCR controls at Wyoming’s subject-toBART units are also predicted to
significantly reduce the number of days
with visibility impacts above 0.5
deciview and 1.0 deciview compared to
baseline emissions scenario. Over all 18
Class I areas modeled, the cumulative
improvement from application of SCR
on all Wyoming BART-subject EGUs is
721 fewer days with visibility
impairment exceeding 0.5 deciview and
595 fewer days with visibility
impairment exceeding 1.0 deciview. Id.,
Table 3–14. These improvements are
relatively uniformly distributed across
the seven Class I areas most impacted by
Wyoming’s subject-to-BART EGUs:
Badlands National Park, Bridger
Wilderness Area, Mt. Zirkel Wilderness
Area, Rawah Wilderness Area, Rocky
Mountain National Park, Savage Run
Wilderness Area, and Wind Cave
National Park.
Response: As described in another
response, EPA did not limit its analysis
of visibility impairment to a single Class
I area. We evaluated visibility
impairment from each BART source at
multiple Class I areas. We presented the
results for each Class I area, and we
considered the visibility impairment at
multiple Class I areas in our BART
determination. The estimates of
visibility impairment presented by the
commenter relied on an overly
conservative estimates of background
ammonia concentrations, and therefore
are likely to overestimate cumulative
visibility benefits.
In regard to the comment concerning
the cumulative visibility benefit of
BART controls on multiple units at a
single source, see the response to a
subsequent comment below.
Comment: It is appropriate to
consider both the degree of visibility
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5129
improvement in a given Class I area as
well as the cumulative effects of
improving visibility across all of the
Class I areas affected. If reducing
emissions from a BART source impacts
multiple Class I areas, then a BART
determination should incorporate those
benefits. It is not justified to evaluate
impacts at one Class I area, while
ignoring others that are similarly
significantly impaired by the BART
source. If emissions from the BART
source are reduced, the benefits will be
spread well beyond only the mostimpacted Class I area, and these benefits
are an integral part of the BART
determination. The BART Guidelines
attempt to create a workable approach to
estimating visibility impairment. The
Guidelines do not attempt to address the
geographic extent of the impairment,
but in effect assume that all Class I areas
are created equal, i.e., widespread
impacts in a large Class I area and
isolated impacts in a small Class I area
are given equal weight for BART
determination purposes. To address the
problem of geographic extent, we look at
the cumulative impacts of a source on
all Class I areas affected, as well as the
cumulative benefits from reducing
emissions. While there may be more
sophisticated approaches to this
problem, we believe that this is the most
practical, given current modeling
techniques and information available.
Response: Contrary to the
commenter’s assertion, we did assess
cumulative visibility impacts for
multiple Class I areas. In our analysis of
visibility impacts, we considered the
visibility improvement at multiple Class
I areas within the 300 kilometers of the
modeling domain. For example, in our
analysis of BART control options for
Naughton, we considered the visibility
improvement at seven Class I areas
(Bridger Wilderness Area, Fitzpatrick
Wilderness Area, Grand Teton National
Park, North Absaroka Wilderness Area,
Teton Wilderness Area, Washakie
Wilderness Area, and Yellowstone
National Park).
Therefore, our proposed rule did not
ignore the visibility improvement that
would be achieved at areas other than
the most impacted Class I area, and we
disagree with the assertions that we did
not consider the impacts at multiple
Class I areas. In the proposed rule, we
did however focus on the visibility
benefits at the most impacted Class I
area.
Comment: EPA has incorrectly
estimated visibility improvement from
all NOX control options at the Laramie
River Station. Wyoming DEQ evaluated
visibility improvements at the two
nearest Class I areas and reported the
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‘‘The cumulative visibility improvement
for SCR, as compared to LNB/OFA,
across Wind Cave National Park and
Badlands National Park (based on the
98th percentile modeled results) was
0.52–0.54 delta deciview for each of the
three units.’’ EPA R8 evaluated the five
closest Class I areas but reported results
for only the Wind Cave National Park.
Response: As described in a previous
response, in our analysis of visibility
impacts, we considered the visibility
improvement at four Class I areas within
300 kilometers of Laramie River.
Modeling results for all Class I areas
considered for each BART source for the
re-proposal were available to the public
during the comment period upon
request. (See ‘‘Summary of EPA’s
Additional Visibility Improvement
Modeling’’). Therefore, our proposed
rule did not ignore the visibility
improvement that would be achieved at
areas other than the most impacted
Class I area, and we disagree with the
assertions that we did not consider the
impacts at multiple Class I areas. In the
proposed rule, we did however focus on
the visibility benefits at the most
impacted Class I area.
Comment: EPA rejected Oklahoma’s
visibility analyses which ‘‘relied upon
pollutant specific modeling to evaluate
the benefits from the use of available
SO2 emission controls.’’ 76 FR 81728,
81740. Rather, EPA modeled in
Oklahoma ‘‘all visibility impairing
pollutants to fully assess the visibility
improvement anticipated from the use
of controls.’’ EPA argued this modeling
took into account ‘‘the complexity of
atmospheric chemistry and chemical
transformation among pollutants.’’ In
Wyoming, EPA noted that Wyoming
provided ‘‘visibility improvement
modeling results that combine[d] the
visibility improvement from NOX, PM
and SO2 control options’’ and that ‘‘EPA
could not ascertain what the visibility
improvement would be from an
individual NOX or PM control option.’’
77 FR 33031. EPA appears to take
contrary positions in Oklahoma and
Wyoming. EPA’s inconsistent positions
are arbitrary and capricious.
Response: As described in a response
to a previous comment, it appears that
the commenter has confused (1)
whether all pollutants were modeled
together; and (2) whether all control
technologies were modeled. All
pollutants were modeled together both
in modeling performed by Wyoming
and by EPA for BART sources in
Wyoming and Oklahoma, consistent
with IWAQM Phase 2 report
recommendations. The additional
modeling performed by EPA was
designed to evaluate visibility
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improvements from certain emissions
reduction technologies. Each of these
simulations also included all other
visibility impairing pollutants, so the
approach used by EPA in Wyoming and
Oklahoma is consistent.
Comment: We are concerned about
the emissions modeled by EPA as
presented in the ‘‘Summary of EPA’s
Additional Visibility Improvement
Modeling.’’ For example, sulfuric acid
mist (H2SO4) emissions from each
PacifiCorp unit are assumed to double
from the baseline and control scenarios
that do not include SCR versus
scenarios with SCR. The only
explanation provided by EPA is that
‘‘the emission rate for . . . total sulfate
rates were increased to account for the
additional production that results from
SCR controls.’’ EPA’s approach in
Wyoming is not consistent with its
approach elsewhere. For example, in its
modeling analysis of addition of SCR at
Colstrip Units 1 and 2 in Montana, EPA
assumed no additional sulfate emissions
from the addition of SCR.
Because H2SO4 must be reported as a
hazardous air pollutant, the Electric
Power Research Institute has developed
a widely-accepted method for
estimating those emissions. Our
analyses indicate a two-orders-ofmagnitude overestimation by EPA of
these visibility-impairing emissions,
which results in an underestimation of
the visibility benefit of adding SCR.
Response: While the method
established by the Electric Power
Research Institute may yield more
accurate H2SO4 emission rates, we have
not found, and the commenter has not
substantiated, that our treatment of
H2SO4 led to meaningfully different
modeled visibility improvement, or for
that matter, influenced the BART
determination in a material manner. In
the modeling conducted by EPA, we set
the sulfuric acid emission rates equal to
those in the State’s modeling analyses
which typically doubled the H2SO4
emission rate between the baseline and
SCR modeling scenarios. In comparison
to the emission rates for SO2 and NOX,
the emission rates for H2SO4 were
trivial. For example, consider Dave
Johnston Unit 3, where the modeled
emission rates for SO2 and NOX in the
baseline scenario were 420.0 lbs/hr and
1671.0 lbs/hr, respectively, while the
modeled emission rate for H2SO4 was
2.6 lbs/hr. Here, in comparison to SO2
and NOX emissions, the emissions rate
of H2SO4 is clearly insignificant and
would have a limited impact on
modeled visibility. The same can be
said for the SCR scenario where the
modeled emission rates for SO2 and
NOX were 420.0 lbs/hr and 163.3 lbs/hr,
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respectively, while the modeled
emission rate for H2SO4 was 5.1 lbs/hr.
In short, the H2SO4 emission rates used
in the modeling were so low that it is
apparent that they have no more than a
negligible impact on the modeled
visibility improvement.
Comment: EPA must consider the
cumulative visibility benefit of BART
controls on multiple units of a single
source. EPA’s BART guidelines make
clear that states must consider
emissions from an entire source in
determining whether a source is subjectto-BART, and further clarify that
multiple units at a single utility
constitute a single source. 40 CFR part
51, App Y, sect. II.A. This is not by
accident or oversight. As EPA stated in
its preamble to the BART Guidelines,
‘‘[a]pplying de minimis levels on a unit
by unit basis . . . could exempt
hundreds of tons of emissions of a
visibility-impairing pollutant from
BART analysis. [I]t is possible that
while emissions from each unit are
relatively trivial, the costs of controlling
emissions from multiple units might be
cost-effective in light of the BARTeligible source’s total emissions of the
pollutant at issue.’’ 70 FR 39104, 39117.
With respect to the RHR requirement
that states must project visibility
impacts of BART controls, the BART
Guidelines state: ‘‘Once you have
determined that your source or sources
are subject to BART, you must conduct
a visibility improvement determination
for the source(s) as part of the BART
determination.’’ 40 CFR part 51, App Y,
sect. IV.D.5. Thus, it is clear that both
visibility impacts and visibility benefits
are to be considered cumulatively for
multiple units at a single source.
This is also consistent with EPA’s
practice in other states. For example,
EPA found it appropriate to consider the
combined visibility impact of pollution
controls on multiple units at a single
facility in determining that BART is
SNCR for Units 1 and 2 of the Colstrip
facility in Montana. Failure to consider
cumulative visibility impacts discounts
the very real effect of source-specific
pollution on regional haze and likewise
the cumulative benefits of potential
retrofits. EPA cannot demonstrate that it
has properly evaluated BART controls
for affected sources without producing
and presenting such a cumulative
analysis.
Response: EPA notes that, in
considering the visibility improvements
reflected in our revised modeling, EPA
interprets the BART Guidelines to
require consideration of the visibility
improvement from BART applied to the
entire BART-eligible source. The BART
Guidelines explain that, ‘‘[i]f the
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emissions from the list of emissions
units at a stationary source exceed a
potential to emit of 250 tons per year for
any visibility-impairing pollutant, then
that collection of emissions units is a
BART-eligible source.’’ In other words,
the BART-eligible source (the list of
BART emissions units at a source) is the
collection of units for which one must
make a BART determination. The BART
Guidelines state ‘‘you must conduct a
visibility improvement determination
for the source(s) as part of the BART
determination.’’ This requires
consideration of the visibility
improvement from BART applied to the
BART-eligible source as a whole. We
note, however, that while our
regulations require states and EPA to
assess visibility improvement on a
source-wide basis, they provide
flexibility to also consider unit-specific
visibility improvement in order to more
fully inform the reasonableness of a
BART determination, but that does not
replace the consideration of visibility
benefit from the source (facility) as a
whole.
In making the BART determinations
in this final action we have considered
visibility improvements at the source,
and then also at the units that comprise
the source. The approach that we used
in our BART decisions for Wyoming is
consistent with the approach that we
used for Montana.
Comment: The commenter submitted
results of back trajectory HYSPLIT
modeling showing that pollutants
reaching certain Class I areas on the
high nitrate haze days did not originate
from Laramie River Station. The
commenter concludes that this analysis
confirms that reducing NOX emissions
from Laramie River would not improve
visibility at these Class I areas.
Response: We disagree with the
comment that the HYSPLIT results
submitted by the commenter can be
used to evaluate the contribution of
Laramie River to visibility impairment
at Wind Cave National Park. The
commenter performed HYSPLIT backtrajectory modeling for 10 days with
high ammonium nitrate concentrations
at Wind Cave National Park. The 10
days were selected from the period from
2001 to 2010, and only two of these
days occurred during 2001 to 2003
baseline period used for the BART
visibility modeling. These two days
were February 24, 2001 and February
14, 2003, when the observed ammonium
nitrate at the IMPROVE monitoring site
at Wind Cave National Park was 41 and
33 inverse Megameters (Mm-1),
respectively. We note that there were
many days during the 2001 to 2003
period on which observed ammonium
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nitrate levels at Wind Cave National
Park were in the range from 10 to 30
Mm-1,133 but the commenter did not
submit HYSPLIT results for these days.
HYSPLIT is a trajectory model similar
to CALPUFF in that both models use
modeled and observed wind field data
to predict the trajectory of pollutants
transported from a source area to a
receptor location. There are differences
in the formulation of the HYSPLIT and
CALPUFF models and differences in the
meteorological data used as input data
for each model, so the predicted
trajectory from each model may vary
somewhat as a result of these
differences. The most notable difference
in the two models is that CALPUFF is
designed to predict both the trajectory
and the chemical conversion of
precursor emissions to fine particulates
and to estimate the concentrations of
ammonium nitrate and other species at
receptor sites, while HYSPLIT simply
predicts the trajectory of the emissions
but does not predict the chemical
transformations nor the concentration of
ammonium nitrate at receptor sites.
We evaluated the CALPUFF results
for February 24, 2001 and February 14,
2003, and found that the HYSPLIT and
CALPUFF results were consistent, i.e.,
the CALPUFF model did not attribute
high levels of ammonium nitrate at
Wind Cave National Park on these two
days to Laramie River. The table of
CALPUFF modeling results 134 shows
that the model predicted a contribution
of nitrate from Laramie River of 0.02
deciview on Feb 24, 2001, or 0.05% of
the observed value, and on Feb 14,
2003, 1.697 deciview, or 5% of the
observed. The small modeled
contribution on these days is consistent
with uncertainty in the HYSPLIT model.
Because the HYSPLIT model does not
estimate the formation of ammonium
nitrate, and because HYSPLIT results
were only submitted for two days
during the 2001 to 2003 baseline
modeling period, these HYSPLIT results
are neither useful nor reliable for
identifying emissions sources that
contribute to visibility impairment at
Wind Cave National Park. The HYSPLIT
and CALPUFF results do indicate that
sources other than Laramie River
contribute to visibility impairment on
the two days with the very highest
ammonium nitrate levels at Wind Cave
during the 2001 to 2003 baseline period.
However, the CALPUFF results indicate
that Laramie River contributes to
133 Document with Wind Cave IMPROVE data, in
the docket.
134 EPA CALPUFF modeling results for Laramie
Rivers Station, in docket: CALPUFF_WY_BART_
bextNO3_BE_LR_Baseline_WindCave_12112013.
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visibility impairment at Wind Cave
National Park.
Comment: EPA improperly
considered ‘‘cumulative visibility
improvement’’ when it rejected
Wyoming’s BART NOX analyses and
required SCR at Naughton Unit 1 and
Naughton Unit 2. (78 FR 34782). Other
comments asserted that EPA improperly
considered ‘‘cumulative visibility
improvement’’ when it rejected
Wyoming’s BART NOX analyses and
required SCR at Dave Johnston Unit 3
(78 FR 34778). Finally, a third set of
comments asserted that EPA R8 has
incorrectly estimated visibility
improvement from all NOX control
options at Wyodak: Wyoming DEQ
evaluated cumulative visibility
improvements at the two nearest Class
I areas (Wind Cave and Badlands
National Parks) while EPA R8 reported
results for only one Class I area.
Response: We disagree with these
comments. In evaluating the visibility
improvement associated with various
control options, EPA interprets the CAA
to require consideration of visibility
improvement at all impacted Class I
areas. Consideration of improvement at
multiple Class I areas, as opposed to just
benefits at the most impacted Class I
area, has often been described as
‘‘cumulative visibility improvement.’’
Despite this terminology, however, an
analysis of cumulative visibility
improvement does not necessarily
require that the deciview improvement
at each area be summed together. While
states or EPA are free to take such a
quantitative approach, they are also free
to use a more qualitative approach.
Here, we chose to rely primarily on the
visibility improvement at the most
impacted Class I area, while also
considering the number of additional
Class I areas that would see
improvement, as well as the level of
improvement at each area. We did not
expressly rely on a summation of
visibility benefits across Class I areas, as
we have done in other regional haze
actions, although this metric was
included in some tables. Finally, in our
analysis of visibility impacts, we
considered the visibility improvement
at both Class I areas within 300
kilometers of Wyodak. The modeling
results for the second proposal for all
Class I areas considered for each BART
source were available to the public
during the comment period upon
request. (See ‘‘Summary of EPA’s
Additional Visibility Improvement
Modeling’’).
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1. BART-Eligible Sources
Comment: OCI Wyoming commented
that it was listed as a BART-eligible
source, but that the facility has an
enforceable cumulative annual NOX
emission limit of 175.2 tons/year.
Therefore, the facility is not a ‘‘major
stationary source’’ and is not BARTeligible.
Response: We agree with this
comment and acknowledge that OCI
Wyoming is not a BART-eligible source.
2. Costs of Controls
Comment: One commenter stated that
it supported EPA’s use of the CCM and
the Integrated Planning Model (IPM) to
calculate costs.
Response: It is noted that EPA has
revised the cost estimates found in the
proposed rule based upon input from
various commenters. The differences in
cost for individual units may result
from: (1) Accounting for site elevation
in the SCR capital cost; (2) Change in
SCR reagent to anhydrous ammonia
from urea; (3) Change in urea SNCR
chemical utilization for Laramie River
units due to high furnace temperature;
(4) Incorporation of some of the costs
provided in comments; (4) Change in
auxiliary electrical cost from market
price to generating, or ‘‘busbar,’’ cost; (5)
Correction of dilution water cost
equation for SNCR; and (6)
Consideration of shorter plant lifetimes
in some instances.
More detailed descriptions of these
changes and how they were addressed
are discussed in a report (Andover
Report) and spreadsheets 135 developed
for EPA’s responses to comments, as
well as in our responses to the specific
comments that are associated with these
changes below.
Comment: Sargent & Lundy’s analysis
provides realistic information regarding
what it likely would cost to install and
operate an SCR system at Laramie River
Station. They include a cost analysis by
Sargent & Lundy that, unlike EPA’s
consultant’s work, follows the BART
Guidelines and EPA’s CCM, and takes
into account key site-specific conditions
at Laramie River Station. This analysis
is far more accurate and reliable than
what was done by EPA’s consultant—it
is a site-specific, from-the-ground-up
analysis done by an engineering firm
that has done more NOX control projects
for EGUs than any other firm in the U.S.
135 Andover Technology Partners, ‘‘Cost of NO
X
Controls on Wyoming EGUs’’, October 28, 2013;
Wyoming EGU BART and Reasonable Progress
Costs—10/28/2013; Wyoming EGU BART and
Reasonable Progress Costs for Jim Bridger—10/28/
2013.
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Sargent & Lundy’s analysis provides
realistic information regarding what it
likely would cost to install and operate
an SCR system at Laramie River. This
analysis strongly supports Wyoming’s
decision to select new LNBs and OFA
as BART for Laramie River Station, not
SNCR or SCR.
Response: We do not agree with this
comment. The BART Guidelines
provide that: ‘‘You should include
documentation for any additional
information used for the cost
calculations, including any information
supplied by vendors that affects your
assumptions regarding purchased
equipment costs, equipment life,
replacement of major components, labor
productivity and rates and any other
element of the calculation that differs
from the Control Cost Manual.’’ 40 CFR
part 51, app. Y, at IV.4.a.
Thus, detailed cost documentation is
necessary to the extent that cost
assumptions differ from the CCM. In
this case, several of Sargent & Lundy’s
cost assumptions for control costs at
Basin Electric’s Laramie River Station
differed from the CCM, but the
necessary supporting documentation
was not provided as part of their report.
Detailed descriptions of the deficiencies
in the cost assumptions are described in
comments specific to the units. As
explained elsewhere in this document,
EPA has accepted some of the revised
costs developed for Basin Electric, but
not others.
Comment: We found that EPA’s
consultant had added 1.2% to the total
capital investment of SCR to account for
‘‘taxes and insurance.’’ The CCM says:
‘‘In many cases property taxes do not
apply to capital improvements such as
air pollution control equipment,
therefore, for this analysis, taxes are
assumed to be zero. The cost of
overhead for an SCR system is also
considered to be zero. An SCR system
is not viewed as risk-increasing
hardware (e.g., a high energy device
such as a boiler or a turbine).
Consequently, insurance on an SCR
system is on the order of a few pennies
per thousand dollars annually.’’ The
BART submittal by PacifiCorp included
a 1.1% sales tax and Basin Electric
included a 4% sales tax, both of which
were applied to the purchased
equipment costs. It is unclear if
application of a sales tax is appropriate
in Wyoming and, if so, what the correct
tax rate is.
Response: To the extent that sales or
property taxes are actually incurred and
increase the cost of the project, they
should be accounted for in the cost. See
CCM at 2.5.4.1 and 2.5.5.8. However, air
pollution control improvements often
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do not result in increased property
taxes. When these taxes are not in fact
applied, they should not be included in
the estimate. The use of 1.2% as an
estimate of property taxes and insurance
is a conservative estimate that is
consistent with EPA’s assumptions in
the IPM documentation. According to
the IPM documentation (version 4.10,
Chapter 8, page 8–11): ‘‘U.S. state
property taxes are approximately 0.9%
based on a national average basis. This
is based on extensive primary and
secondary research conducted by ICF
using property tax rates obtained from
various state agencies. . . . Insurance
costs are approximately 0.3%. This is
based on estimates of insurance costs on
a national average basis.’’ 136
As noted by the commenter, these
costs may not in fact apply for
environmental upgrades or may be
much less than estimated. EPA did not
have information on the applicability of
property taxes at the time we conducted
our cost estimates and conservatively
assumed a reasonable amount. We also
note that the commenter did not provide
sufficient information to support a
different property tax or insurance rate.
With regard to sales tax, the IPM
algorithm for SCR cost is based upon
historical projects and incorporates
typical levels of sales tax. That is, the
capital costs provided by the
algorithm(s) are inclusive of sales tax.
Accordingly, for the purpose of the
BART cost estimates, and without
additional data to determine what sales
taxes would actually apply, EPA has
relied on the assumptions in the IPM
algorithm.
Comment: EPA states in its FIP Action
(78 FR 34749): ‘‘For all control
technologies, EPA has identified
instances in which Wyoming’s sourcebased cost analyses did not follow the
methods set forth in the EPA Control
Cost Manual. For example, Wyoming
included an allowance for funds used
during construction and for owners
costs and did not provide sufficient
documentation such as vendor estimates
or bids.’’
With respect to AFUDC, another
utility (Oklahoma Gas and Electric)
argued in a similar regional haze setting
that: ‘‘AFUDC provides a way of
measuring the real cost of interest over
the construction period. AFUDC
accounts for the time value of money
associated with the distribution of
construction cash flows over the
construction period, which may be
approximately 18 months for an SCR
project.’’ Total capital investment, as
136 https://www.epa.gov/airmarkets/progsregs/epaipm/BaseCasev410.html#documentation.
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defined in the CCM, includes all costs
required to purchase equipment needed
for the control system (purchased
equipment costs), the costs of labor and
materials for installing that equipment
(direct installation costs), costs for site
preparation and building, working
capital, and off-site facilities.
A cost breakdown of total capital
investment (as defined above) is
presented in several examples in the
CCM. For example, Table 1.4 (page
1–32 of Section 4—NOX Controls) and
Table 2.5 (page 2–44 of Section 4—NOX
Controls) therein explicitly identify
AFUDC as component ‘‘E’’ of the TCI,
where TCI = D + E + F + G + H + I,
where: D = Total Plant Cost; E =
AFUDC; F = Royalty Allowance; G =
Preproduction Cost; H = Inventory
Capital; I = Initial Catalyst and
Chemicals.
References 9 and 10 on page 2–38 of
the CCM explicitly include AFUDC as a
cost component and reference two
reports, by Shattuck and Kaplan, in
support of its use. The EPA built upon
this knowledge base and costing
methodology in its publication of the
CCM in 2002. Thus, the CCM allows the
time value of money, measured by the
real discount rate, to be incorporated
into the cost estimate.
Section 2.3.1 of the CCM (Elements of
Total Capital Investment) describes the
need for total capital investment to
include all expenditures incurred
during the construction phase of the
project, including direct costs, indirect
costs, fuel and consumables expended
during start-up and testing, and other
capitalized expenses. The only items
explicitly mentioned to be excluded are
common facilities that already exist at
the site. AFUDC is part of the expense
that will be incurred with the
installation of a large air pollution
control system, and the accepted
practice in the utility industry and by
financial institutions is to treat AFUDC
as a capitalized expenditure. This
approach is recognized in publications
by the U.S. Department of Energy—
Energy Information Administration,
such as the Annual Energy Outlook, and
in publications by the Electric Power
Research Institute, such as the
Technical Assessment Guide (EPRI
TAG). As previously mentioned, the
EPA clearly followed this approach in
its studies of retrofit costs of SO2 and
NOX in the years leading up to its
publication of the CCM. Furthermore,
AFUDC has been included in several
other coal-fired boiler BART
determinations, and AFUDC is included
as a line item in EPA’s Coal Quality
Environmental Cost (CUECost)
worksheets for flue gas desulfurization
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(FGD) control systems. In cases where
the time value of money during the
construction period would be
significant (e.g., projects with longer
construction periods such as the
installation of SCR), the CCM clearly
allows inclusion of AFUDC.
PacifiCorp supports and adopts by
reference Oklahoma Gas and Electric’s
argument regarding including AFUDC
in project cost estimates. Whether or not
AFUDC is included in project cost
estimates does not materially impact the
results reached under the EPA CCM
method, its inclusion should not
constitute a basis for EPA to reject
Wyoming’s entire cost assessments.
PacifiCorp has provided tables that
provide comparisons of PacifiCorp’s
project specific EPA CCM method
results where AFUDC is excluded in
one set of costs and is included in the
other to demonstrate this point.
Response: We disagree with
commenters’ assertions that AFUDC is a
cost that should be incorporated into
our cost analysis, as it is inconsistent
with CCM methodology. The utility
industry uses a method known as
‘‘levelized costing’’ to conduct its
internal comparisons, which is different
from the methods specified by the CCM.
Utilities use ‘‘levelized costing’’ to allow
them to recover project costs over a
period of several years and, as a result,
realize a reasonable return on their
investment. The CCM uses an approach
sometimes referred to as overnight
costing, which treats the costs of a
project as if the project were completed
‘‘overnight’’, with no construction
period and no interest accrual. Since
assets under construction do not
provide service to current customers,
utilities cannot charge the interest and
allowed return on equity associated
with these assets to customers while
under construction. Under the
‘‘levelized costing’’ methodology,
AFUDC capitalizes the interest and
return on equity that would accrue over
the construction period and adds them
to the rate base when construction is
completed and the assets are used.
Although it is included in capital costs,
AFUDC primarily represents a tool for
utilities to capture their cost of
borrowing and return on equity during
construction periods. AFUDC is not
allowed as a capitalized cost associated
with a pollution control device under
CCM’s overnight costing methodology,
and is specifically disallowed for SCRs
(i.e., set to zero) in the CCM.137
Therefore, in reviewing other BART
determinations, EPA has consistently
137 CCM (Tables 1.4 and 2.5 show AFUDC value
as zero).
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excluded AFUDC.138 EPA’s position
regarding exclusion has been upheld in
the United States Tenth Circuit Court of
Appeals.139
The fact that CUECost, the EPRI TAG,
and the Department of Energy cost
estimates, and even cost estimates used
as the basis for IPM typically include
AFUDC is immaterial in this case
because, for this purpose, overnight cost
methodology is used and AFUDC is not
included in that methodology.
Finally, we reject the commenter’s
assertion that Wyoming’s inclusion of
AFUDC did not provide a material basis
for EPA to disapprove portions of the
State’s SIP. Inclusion of AFUDC
increases total project costs of SCR by
several million dollars. For example,
Attachment 4 to PacifiCorp’s comment
letter shows that AFUDC for Dave
Johnston Unit 4 would add more than
$9.5 million dollars to the capital costs
of SCR. We find that amounts of this
magnitude are not trivial when
assessing the costs of compliance.
Comment: Sargent & Lundy’s cost
estimate does include AFUDC, which
accounts for the interest charges that
would be incurred by Basin Electric
during SCR construction. AFUDC is a
real and a significant cost on capital
intensive, long-term projects such as
SCR installation, which require
financing over a construction period of
up to four years. Indeed, to exclude
AFUDC would inappropriately bias the
cost estimate in favor of high capital
intensity projects. Therefore, consistent
with industry practice, Sargent & Lundy
included AFUDC, calculated based on a
typical SCR construction project cash
flow assuming a real interest rate of 7%.
The inclusion of AFUDC is not, as
EPA asserts, inconsistent with either the
BART Guidelines or the CCM. See 78 FR
34749. The CCM simply references
‘‘Total Capital Investment,’’ which
includes ‘‘all costs required to purchase
equipment needed for the control
system,’’ as well as ‘‘working capital.’’
CCM 2.3.1, page 2–5 (emphasis added).
This includes costs required to purchase
equipment needed for the control
system (purchased equipment costs), the
costs of labor and materials for
installing that equipment (direct
installation costs), costs for site
preparation and building, working
138 See, e.g., 77 FR 20894, 20916–17 (Apr. 6,
2012) (explaining in support of the North Dakota
Regional Haze FIP, ‘‘we maintain that following the
overnight method ensures equitable BART
determinations * * *.’’); 76 FR 52388, 52399–
52400 (August 22, 2011) (explaining in the New
Mexico Regional Haze FIP that the Manual does not
allow AFUDC)
139 Oklahoma v. U.S. EPA, 723 F.3d 1201 (10th
Cir. 2013).
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capital, and off-site facilities. Id.
Nowhere in the CCM does EPA state
that AFUDC is not an appropriate cost,
particularly with respect to long-term,
capital intensive pollution control
projects. And even if the CCM made
such an assertion, inclusion of AFUDC
in a cost estimate cannot be grounds for
SIP disapproval because: (1) the CCM is
not binding for purposes of making
BART determinations, and (2) requiring
states to exclude AFUDC is not
consistent with Congress’ general
directive that states include ‘‘costs of
compliance’’ in their BART
determinations.
The CAA requires states to consider
in their BART determinations the ‘‘costs
of compliance,’’ but does not further
define the term. See 42 U.S.C. 7491.
EPA’s regulations codify the BART
factors, but neither the regulations nor
the BART Guidelines in Appendix Y
purport to restrict in any manner the
categories of costs that states should
consider when making a BART
determination. See 70 FR 39166–39168.
AFUDC is a ‘‘cost of compliance.’’ Basin
Electric cannot fund large capitalintensive projects like SCR without
financing, and the costs related to such
financing are real and substantial.
Consideration of AFUDC is therefore
entirely consistent with the CAA’s
broad reference to ‘‘costs of
compliance,’’ and excluding AFUDC
would be inconsistent.
In this case, even if AFUDC is
excluded from the total annual costs,
the costs of installing SCR do not
decrease substantially enough to justify
SCR. Sargent & Lundy performed
sensitivity analyses demonstrating that
the cost-effectiveness of SCR at Laramie
River remains at between $8,531 per ton
of NOX removed and $9,048 per ton of
NOX removed even if AFUDC is
excluded. Furthermore, if the
maintenance cost and labor rate of 1.5%
also is factored into the analysis,
consistent with the CCM, as opposed to
the lower 0.25% used by Sargent &
Lundy, the cost-effectiveness remains
above $8,500 per ton of NOX removed.
Sargent & Lundy also performed a
sensitivity analysis demonstrating that
including property taxes and insurance
as 1.2% of total capital investment,
consistent with the approach taken by
Andover but not with the CCM
approach, more than offsets the
exclusion of AFUDC. S&L Evaluation
section 7.1.4, Table 10.
Response: EPA agrees that AFUDC
can be a substantial overall cost on large
capital projects that extend over a
period of several years. However, as
noted in the previous response, the
CCM clearly excludes AFUDC in the
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overnight cost method. Furthermore, as
we explain in more detail in responses
to comments that pertain to specific
sources, we disagree with the
commenter’s estimates for cost
effectiveness for the Laramie River
units.
Comment: Commenters assert that
EPA’s regional haze FIP is flawed
because it failed to provide sufficient
documentation, such as vendor
estimates or bids to validate its
estimates. EPA attempts to justify its
approach by stating: ‘‘In our revised cost
analyses, we have followed the structure
(emphasis added) of the EPA CCM,
though we have largely used the
Integrated Planning Model cost
calculations to estimate direct capital
costs and operating and maintenance
costs.’’ 78 FR 34749.
EPA did not explain what it meant by
following the ‘‘structure’’ of the manual,
versus simply following the manual. By
contrast, PacifiCorp solicited and
incorporated vendor estimates into
these comments. This new information,
which EPA must incorporate into new
BART analyses to the extent EPA issues
a final regional haze FIP, validates
Wyoming’s BART analyses cost of
control estimates. In addition, it further
quantifies the inaccuracies in EPA’s
development and use of purported new
information that in no way qualifies as
vendor estimates, bids, or any type of
site-specific vendor information.
Response: We do not agree with this
comment. By following the ‘‘structure’’
of the manual, EPA included all of the
cost elements that the CCM indicates
should be included, while excluding
those that should not (such as AFUDC).
In other words, EPA employed the
overnight cost method as is required for
BART analyses. The BART Guidelines
require that the CCM be followed unless
deviations from it are clearly
documented and explained.
PacifiCorp received bids from vendors
and EPA has incorporated information
from these bids into its revised cost
estimates. However, for reasons
described elsewhere in response to
comments, EPA has not accepted all of
the costs. The BART Guidelines state:
‘‘You should include documentation for
any additional information you used for
the cost calculations, including any
information supplied by vendors that
affects your assumptions regarding
purchased equipment costs, equipment
life, replacement of major components,
and any other element of the calculation
that differs from the CCM.’’ 70 FR
39166.
With regard to Basin Electric, vendor
quotes for the Laramie River Station
were not supplied. As Basin Electric
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indicated in its comments, ‘‘[t]he LRS
cost estimates are conceptual in nature;
thus, S&L did not procure equipment
quotes specifically for the LRS control
systems. Rather, equipment costs for the
LRS projects are based on conceptual
designs developed for the control
systems, preliminary equipment sizing
developed for the major pieces of
equipment, and recent pricing for
similar equipment.’’
In effect, like the IPM cost algorithms,
the method that underlies Sargent &
Lundy’s estimate for Basin Electric is
empirically based on past data, and not
vendor quotes developed specific to
Laramie River. We have, however,
accepted some of the costs submitted by
Basin Electric and not accepted others.
Comment: Even if EPA had the
authority to require the use of the CCM,
which it does not, EPA’s insistence on
Wyoming’s strict compliance with the
costing methodology set forth in the
CCM, without adjusting the
methodology to account for important
site-specific factors, leads to an
erroneous and arbitrary and capricious
result. This is not required by the CCM.
Indeed, the manual expressly discounts
the usefulness of the costing
methodology to power plants generally
and to SCR control systems specifically,
and it acknowledges that deviation from
the methodology may be appropriate
based on a user’s engineering judgment.
The CCM provides general costing
methodology for stationary source air
pollution control technologies,
applicable primarily to regulatory
development where a rough order of
magnitude estimate is appropriate. The
introduction to the manual also caveats
its usefulness when assessing control
costs at power plants, which use
different cost accounting. Cost Manual
section 1.1, page 1–3. Specifically, it
states that ‘‘[e]lectrical utilities generally
employ the EPRI Technical Assistance
Guidance (TAG) as the basis for their
cost estimation processes.’’ Id. In a
footnote, it explains that while power
plants might still use the manual,
‘‘comparisons between utilities and
across the industry generally employ a
process called ‘levelized costing’ that is
different from the methodology used
here.’’ Id. section 1.1, page 1–3 n.1.
The CCM also generates rough
estimates of costs that are less accurate
than the site-specific cost factors that
are more appropriate for BART
determinations at a large power plant.
The manual is used heavily in
regulatory development, and the costing
methodology is geared specifically to
avoid the necessity of site-specific
information and to enable estimates to
be prepared at ‘‘relatively low cost with
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minimum data.’’ Id. section 2.2, page
2–3 (internal quotations omitted).
However, the level of accuracy is much
lower than that for estimates using sitespecific information. The cost
estimating procedure can provide a
‘‘rough order of magnitude,’’ estimate
that is ‘‘nominally accurate to within ±
30%.’’ Id. section 1.2, page 1–4. Indeed,
‘‘EPA does not claim cost estimates for
industry at a greater than study level
accuracy for industrial users’’ because
‘‘the industrial user will necessarily
have much more detailed information
than the generic cost and sizing
information.’’ Id. section 2.2, page 2–3,
2–4.
Where the user has detailed sitespecific information, the manual does
not contemplate strict adherence to its
costing methodology. Users may
‘‘exercise ‘engineering judgment’ on
those occasions when the procedures
may need to be modified or
disregarded.’’ Id. section 1.3, page 1–7.
With respect to estimating factors used
in cost estimates, ‘‘the application of an
appropriate factor requires the
subjective application of the analyst’s
best judgment.’’ Id. section 2.5.4.1, page
2–28. The manual is designed to
provide a tool box for estimating costs
that can be helpful to the engineer, but
‘‘[t]he bottom line is that there is no
clear-cut ‘cookbook’ process through
which the analyst will be able to make
the right informed decision each time,
and the formalized costing methodology
employed by the Manual is only part of
that process.’’ Id. section 2.6, page 2–37.
With respect to SCR cost estimations,
the CCM is no more than a ‘‘tool to
estimate study-level costs for high-dust
SCR systems.’’ Id. section 2.4, page
2–40. The ‘‘[a]ctual selection of the most
cost-effective option should be based on
a detailed engineering study and cost
quotations from the system suppliers.’’
Id. This requirement for a more detailed
study relying on site-specific factors is
necessary because, as EPA
acknowledges, the CCM’s assumptions
regarding capital investment for SCR are
inaccurate. Id. section 2.5.4.1, page
2–27. For systems like SCR, ‘‘the control
in question is either so large or so sitespecific in design that suppliers design,
fabricate, and construct each control
according to the specific needs of the
facility.’’ Id. section 2.5.4.1, page 2–27.
Thus, for these systems, ‘‘the Manual
deviates from its standard approach of
providing study level costs and, instead,
provides a detailed description of the
factors that influence the TCI [total
capital investment] for the analyst to
consider when dealing with a vendor
quotation.’’ Id. Under these
circumstances, EPA acknowledges that
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getting vendor quotes may be difficult
because they cannot be done in an ‘‘offthe-shelf’’ fashion. Id. The engineering
judgment of the manual’s user is
especially critical in estimating the costs
of an SCR retrofit: ‘‘Probably the most
subjective part of the cost estimate
occurs when the control system is to be
installed on an existing facility.’’ Unless
the original designers had the foresight
to include additional floor space and
room between components for new
equipment, the installation of retrofitted
pollution control devices can impose an
additional expense to ‘‘shoe-horn’’ the
equipment into the right locations. For
example, an SCR reactor can occupy
tens of thousands of square feet and
must be installed directly behind a
boiler’s combustion chamber to offer the
best environment for NOX removal. For
these boilers, there is generally little
room for the reactor to fit in the existing
space and additional ductwork, fans,
and flue gas heaters may be needed to
make the system work properly.
To quantify the unanticipated
additional costs of installation not
directly related to the capital costs of
the controls themselves, engineers and
cost analysts typically multiply the cost
of the system by a retrofit factor. The
proper application of a retrofit factor is
as much an art as it is a science, in that
it requires a good deal of insight,
experience, and intuition on the part of
the analyst. The key behind a good cost
estimate using a retrofit factor is to make
the factor no larger than is necessary to
cover the occurrence of unexpected (but
reasonable) costs for demolition and
installation. Such unexpected costs
include, but are certainly not limited to,
the unexpected magnitude of
anticipated cost elements; the costs of
unexpected delays; the cost of
reengineering and re-fabrication; and
the cost of correcting design errors. Id.
section 2.5.4.2, page 2–28. The CCM
cannot properly account for these
uncertainties and thus provides that
users can apply a ‘‘retrofit factor’’ of up
to 50 percent to account for them. Id.
EPA notes that ‘‘[s]ince each retrofit
installation is unique, no general factors
can be developed.’’ Id. 2.5.4.2, page
2–29.
In sum, the BART Guidelines and
CCM were drafted and are to be applied
as guidelines to assist the states in their
decision making, not as inflexible
mandates. Knowing this, states like
Wyoming follow the BART Guidelines
generally but make the necessary
localized and individualized
adjustments required to generate
realistic, rather than formalistic, cost
estimates. Accordingly, EPA should
expect the states to deviate on occasion,
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5135
not to slavishly follow the BART
Guidelines and CCM to the point of
generating artificial (and unrealistic)
cost estimates. Yet that is now exactly
what EPA contends the states must do.
EPA’s current approach to using the
BART Guidelines and manual as
grounds for disapproval without
deference to the states’ authority and
local control is unreasonable, erroneous,
and arbitrary and capricious.
Response: There are only very limited
situations in which a state or EPA can
depart from the CCM cost methodology.
‘‘The basis for equipment cost estimates
also should be documented, either with
data supplied by an equipment vendor
(i.e., budget estimates or bids) or by a
referenced source (such as the OAQPS
CCM, Fifth Edition, February 1996, EPA
453/B–96–001). In order to maintain
and improve consistency, cost estimates
should be based on the OAQPS CCM,
where possible. The CCM addresses
most control technologies in sufficient
detail for a BART analysis. The cost
analysis should also take into account
any site-specific design or other
conditions identified above that affect
the cost.’’ 70 FR 39166.
The guidelines for BART
determinations make it clear that the
CCM is the intended methodology for
conducting a BART cost determination.
It also states why: To maintain and
improve consistency. However, the
CCM does state that site-specific
conditions should be incorporated. Sitespecific conditions could include space
constraints, or a design feature that
could complicate installing a control.
However, the BART Guidelines are clear
that the analyst should document any
deviations from the CCM: ‘‘You should
include documentation for any
additional information you used for the
cost calculations, including any
information supplied by vendors that
affects your assumptions regarding
purchased equipment costs, equipment
life, replacement of major components,
and any other element of the calculation
that differs from the CCM.’’ 70 FR
39166.
In fact, the record does not point to
any unusual circumstances that explain
why SCR costs in Wyoming should be
so much higher than costs of SCR at
other similar facilities. As will be
demonstrated in responses to comments
that are specific to the individual units,
the commenters did not identify any
unique features of their plants that
would make of the installation of an
SCR so difficult that the cost would be
outside the range of what has been
experienced elsewhere, even accounting
for such things as elevation, which is
discussed later in these responses to
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comments. The BART Guidelines also
provide the following explanation,
which makes it clear that other cost
methods are supplemental, not
replacements for the CCM cost method:
‘‘We believe that the CCM provides a
good reference tool for cost calculations,
but if there are elements or sources that
are not addressed by the CCM or there
are additional cost methods that could
be used, we believe that these could
serve as useful supplemental
information.’’ 70 FR 39127.
Although the focus in the second
quote is ensuring the remaining useful
life is incorporated into the amortization
schedule, this passage affirms that the
CCM’s annualized cost methodology
should be followed. The following quote
from the same page of the BART
guidelines sheds light on the type of
costing methodology employed by the
CCM, ‘‘capital and other construction
costs incurred before controls are put in
place can be rolled into the first year, as
suggested in EPA’s OAQPS CCM.’’
Although this passage is again focused
on the remaining useful life, the text we
reproduce is a reference to the basic
CCM cost methodology—the overnight
method. That is what is meant with the
reference of rolling future costs into the
first year. The ‘‘all in’’ method that
OG&E used does not do that—it projects
costs to a future date. Although the CCM
does not use the term, ‘‘overnight cost,’’
it is widely used in industry.
The U.S. Energy Information
Administration defines ‘‘overnight cost’’
as ‘‘an estimate of the cost at which a
plant could be constructed assuming
that the entire process from planning
through completion could be
accomplished in a single day. This
concept is useful to avoid any impact of
financing issues and assumptions on
estimated costs.’’ 140 In effect, the
overnight cost is the present value cost
that would have to be paid as a lump
sum up front to completely pay for a
construction project.
As will be described in EPA’s other
responses to comments regarding
specific plants, commenters did not
provide the documentation required
under the RHR to demonstrate why their
costs were so much higher than costs for
other similar units. Such documentation
would include any vendor quotes to
include scope of supply, explanations of
labor productivity issues with
supporting documentation, and other
concerns raised by commenters and
140 EIA, ‘‘Updated Capital Cost Estimates for
Electricity Generation Plants,’’ November 2010,
footnote. 2. Available at: https://www.eia.gov/oiaf/
beck_plantcosts/?src=email.
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addressed in more detail in other
comments.
Comment: Sargent & Lundy is both a
design and engineering firm and a
system supplier, and it has provided
exactly the type of detailed scopinglevel engineering study for SCR
contemplated by the CCM when
selecting the most cost-effective NOX
control device. EPA acknowledges that
with respect to SCR cost estimations,
the CCM is no more than a ‘‘tool to
estimate study-level costs for high-dust
SCR systems.’’ CCM section 2.4, page
2–40. For systems such as SCR, ‘‘the
control in question is either so large or
so site-specific in design that suppliers
design, fabricate, and construct each
control according to the specific needs
of the facility.’’ Id. section 2.5.4.1, page
2–27. See also id. at section 2.3, page
2–30 (‘‘the design is highly sitespecific.’’). Importantly, the ‘‘[a]ctual
selection of the most cost-effective
option should be based on a detailed
engineering study and cost quotations
from the system suppliers.’’ Id. at
section 2.6, page 2–43.
The Sargent & Lundy Evaluation
provides a cost estimate not based on
the general, broad brush assumptions
set forth as examples in the CCM, but on
a conceptual design of SCR at Laramie
River based on site-specific variables
and Sargent & Lundy’s extensive
knowledge of, and experience with, SCR
installations on coal-fired utility boilers.
Based on this conceptual design,
Sargent & Lundy estimated equipment
costs using example vendor quotes for
similar projects, and used appropriate
commodity pricing references, rates for
labor based on industry publications
and locality-specific data, and, where
necessary, allowances.
Response: As EPA has noted in
previous responses to comments, the
CCM is a good reference tool for
estimating costs. With regard to Sargent
& Lundy’s estimates at Laramie River
Station, EPA has found deficiencies in
the cost estimates or underlying
assumptions that will be discussed in
more detail in comments that are
specific to units.
Comment: One commenter asserted
that the EPA’s cost evaluations
overestimated the annualized capital
costs of BART options by assuming an
unrealistically high interest rate, which
is particularly extreme in the cost
estimates for SCR because of its
relatively higher capital costs than the
other control technologies evaluated.
The commenter calculated and
submitted documentation of what the
commenter considers to be the real cost
of capital interest to PacifiCorp, which
was 5.66 percent, and to Basin Electric,
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which was around 2 percent. According
to the commenter, the EPA continues to
assume a much higher 7 percent interest
rate, apparently based on the EPA’s
mistaken belief that this rate is
supported by the CCM. The commenter
stated that while the CCM states the
social interest rate ‘‘is currently set at
seven percent’’ by the Office of
Management and Budget (OMB), it
references the interest rate established
by OMB in 1992, whereas the OMB
updates interest rates yearly and the
current social interest rate is 1.7 percent
for a 20-year period (citing OMB
Circular A–94, App. C (revised Dec.
2012)).141 The commenter concluded
that even if EPA were correct in
applying the social interest rate, it
should have used the current published
OMB rate in accordance with the CCM’s
direction.
The commenter went on to contend
that the CCM recommends a sourcespecific interest rate for BART and
reasonable progress determinations,
rather than the social interest rate
applied in promulgation of regulations.
According to the commenter, the
7-percent ‘‘social interest rate’’ is used
to estimate the cost to society of taking
an action. However, the CCM states that
this social interest rate ‘‘is probably not
appropriate for industry.’’ The
commenter noted that the RHR requires
the EPA to make case-by-case
determinations of ‘‘the costs of
compliance’’ for identified BART and
reasonable progress options, which the
commenter interprets as being the actual
cost to the source of implementing the
studied alternatives. The commenter
indicated that where the EPA, the state,
or industry is evaluating ‘‘the economic
impact that [air-pollution control]
equipment would have upon the
source,’’ a source-specific interest rate is
appropriate. The commenter concluded
that the EPA erred in relying on a
generic and outdated 7-percent social
interest rate that resulted in a
particularly inflated estimate of SCR
costs, and asserted that in recalculating
the annualized capital costs of control
technologies, the EPA must either use
the current social interest rate of 1.7
percent, or more appropriately, sourcespecific rates of 5.66 percent for
PacifiCorp Units and 2 percent for Basin
Electric Units.
Response: We have retained the use of
a 7-percent interest rate in calculating
the capital recovery factor. For cost
analyses related to government
regulations, an appropriate ‘‘social’’
interest (discount) rate should be used,
141 https://www.whitehouse.gov/sites/default/files/
omb/assets/a94/dischist-2013.pdf.
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not the source’s actual rate of
borrowing. OMB Circular A–4,
providing Federal agencies guidance on
developing regulatory analyses, and
dated September 17, 2003, reiterates the
guidance found in the earlier Circular
A–94: ‘‘As a default position, OMB
Circular A–94 states that a real discount
rate of 7 percent should be used as a
base-case for regulatory analysis. The 7
percent rate is an estimate of the average
before-tax rate of return to private
capital in the U.S. economy, based on
historical data. It is a broad measure that
reflects the returns to real estate and
small business capital as well as
corporate capital. It approximates the
opportunity cost of capital, and it is the
appropriate discount rate whenever the
main effect of a regulation is to displace
or alter the use of capital in the private
sector.’’ 142
In addition, EPA calculated capital
recovery factors using 3-percent and
7-percent interest rates in determining
cost-effectiveness for the Regulatory
Impact Analysis for the BART
Guidelines.143 The 3-percent rate is
mainly used when private consumption
displacement is the main impact of a
regulatory action. This cost of
retrofitting power plants for this action
displaces private capital far more than
private consumption, so 3-percent is not
an interest rate that is applicable here.
We consider our use of an interest rate
of 7-percent to calculate capital recovery
to be a conservative approach.
Finally, the interest rate cited by the
commenter from Appendix C to OMB
Circular A–94, 1.7 percent, is for an
altogether different purpose than the
type of regulatory analysis supporting
today’s rule. According to the discount
rate policy described in Circular A–94,
interest rates contained in Appendix C,
which reflect Treasury borrowing rates,
are for the purpose of internal planning
decisions of the Federal Government.
This is in contrast to regulatory actions,
for which as noted above, the circular
prescribes use of a ‘‘real discount rate of
7 percent.’’ 144
Comment: One commenter stated that
the EPA used the IPM default cost for
auxiliary power of $0.06/kWhr for all of
the control scenarios evaluated, which
is much higher than the auxiliary power
cost commonly used in cost142 Office of Management and Budget, Circular A–
4, Regulatory Analysis, https://www.whitehouse.gov/
omb/circulars-a004_a_4/.
143 ‘‘Regulatory Impact Analysis for the Final
Clean Air Visibility Rule or the Guidelines for Best
Available Retrofit Technology (BART)
Determinations Under the Regional Haze
Regulations,’’ EPA–0452/R–05–004 (June 2005).
144 https://www.whitehouse.gov/omb/circulars_
a094#8.
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effectiveness analyses. The commenter
asserted that the appropriate cost of
auxiliary power to use in a costeffectiveness analysis is the busbar cost
of power to run the plant, not the cost
of power sold. According to the
commenter, auxiliary power is the
power required to run the plant, or
power not sold, and cost-effectiveness
analyses are based on the cost to the
owner to generate electricity, or the
busbar cost, not market retail rates. The
commenter indicated that the sitespecific data reported by PacifiCorp to
the Federal Energy Regulatory
Commission (FERC) in 2010 indicates
that the busbar power cost for the
Wyoming PacifiCorp plants is typically
in the range of $0.02/kWhr to $0.03 lb/
kWhr, and for Basin Electric’s Laramie
River Station, the company used a cost
of $0.015/kWhr, which is consistent
with the busbar power cost.
Response: In EPA’s original analysis,
we used the default values for electricity
in the IPM model, although we agree
that the cost of power used for auxiliary
loads should be the cost of the owner to
generate the electricity rather than the
market price it could be sold at. EPA has
reviewed FERC Form 1 for
PacifiCorp 145 and has incorporated in
our revised costs for each plant the
stated cost of electricity per net kWh.
For Laramie River Station, the costs in
their July 2008 BART analysis 146 are
used, as these are more consistent with
PacifiCorp’s reported cost of generation
(as reported to FERC) than the values
later used by Basin Electric or by EPA
in our original cost analysis (that our
proposed action was based on), which
are more reflective of retail power prices
rather than the cost to generate.
Comment: One commenter argued
that the IPM model is not appropriate
for generating site-specific cost
estimates to evaluate the costeffectiveness of BART projects because
it does not account for those sitespecific requirements that significantly
impact overall project costs.
Response: As described in our
proposal, the IPM is a multi-regional
linear programming model of the U.S.
electric power sector. IPM relies upon a
very large number of data inputs and
provides forecasts of least-cost capacity
expansion, electricity dispatch, and
emission control strategies for meeting
145 FERC Financial Report, FERC Form No. 1:
‘‘Annual Report of Major Electric Utilities,
Licensees and Others and Supplemental Form 3Q:
Quarterly Financial Report, PacifiCorp, Year/Period
of Report 2010/Q4,’’ pgs 402.2, 403, 403.2, see line
35.
146 Black & Veatch, ‘‘Basin Electric Power
Cooperative Laramie River Station Refined BART
Visibility Modeling,’’ July 24, 2008, pg 25 of 176.
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energy demand and environmental,
transmission, dispatch, and reliability
constraints. EPA has used IPM to
evaluate the cost and emissions impacts
of proposed rules, such as the recent
Mercury and Air Toxics Standard
(MATS).147
We wish to clarify that, for our
proposed action on Wyoming’s Regional
Haze SIP, we did not actually run IPM.
Rather, we used information from one
component of IPM, specifically, the
component that develops the costs of air
pollution control technologies. Broadly
speaking, IPM relies upon numerous
components and sub-components to
specify constraints and variable values
that feed into the model algorithms used
during an actual IPM model run. The air
pollution control cost development
component is just one of these
numerous components. We relied upon
the cost information and equations
contained in this component by
manually placing them into a
spreadsheet that calculated the capital,
operating, and maintenance costs
associated with pollution control
options. While we relied upon the
results of these spreadsheet
calculations, we did not then use those
results to run IPM, as the type of
information generated by an actual IPM
model run (e.g., generation dispatch
decisions, capacity decisions) is not
relevant to our action.
We documented our use of the
equations from IPM’s air pollution
control technology cost component by
placing the raw cost calculation
spreadsheets in the docket for our
proposal.148 These spreadsheets contain
the IPM equations, corresponding
variable values, selected notes regarding
assumptions and variable ranges, as
well as selected tables from IPM Base
Case v4.10 documentation. Because we
did not perform an actual IPM model
run, the spreadsheet and contractor’s
report in the docket for our proposal
sufficiently document our use of the
cost methodologies from the IPM air
pollution control cost component.
We disagree with commenters’
characterization of the costdevelopment methodology contained in
IPM as generalized and inadequate for
performing site-specific cost estimates.
As noted in the documentation for
IPM’s cost-development methodology
for SCR, the methodology is based upon
147 https://www.epa.gov/airmarket/progsregs/epaipm/docs/SuppDoc410MATS.pdf.
148 Wyoming EGU BART and Reasonable Progress
Costs—10/28/2013; Wyoming EGU BART and
Reasonable Progress Costs for Jim Bridger—10/28/
2013.
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two databases of actual SCR projects.149
These databases include 2004 and 2006
industry cost estimates prepared for the
Midwestern Ozone Group, and a
proprietary in-house database
maintained by engineering firm Sargent
& Lundy. The Midwestern Ozone Group
information was cross-referenced with
actual 2009 projects, and escalated
accordingly. Sargent & Lundy then used
the information in these databases to
develop the equations described in the
cost component, taking into account the
pre-control NOX emission level, degree
of reduction, coal type, facility size, and
numerous other unit-specific factors.
While a costly engineering evaluation
that included site visits in addition to
use of satellite imagery might produce a
more refined cost estimate, we disagree
that our approach does not produce sitespecific estimates. As noted by EPA in
response to other comments, EPA’s use
of satellite imagery enabled us to
evaluate each of the major site-specific
issues raised by commenters.
Specifically, we input several sitespecific factors, such as fuel type,
baseline NOX level, reagent cost and
type, level of NOX reduction, sitespecific power and reagent costs, etc.
into the algorithm. The algorithm also
provides for adjustment of cost to
account for retrofit difficulty. The CCM
at section 2.5.4.2 (page 2–28 of Section
1 Chapter 2) calls for a retrofit difficulty
factor to account for the site-specific
costs associated with a retrofit, such as
demolition or moving existing
equipment, etc. A retrofit factor is also
used in the IPM algorithm, making it
consistent with the approach used in
the CCM. Per the documentation for the
IPM algorithms: ‘‘The formulation of the
SCR cost estimating model is based
upon two databases of actual SCR
projects. The comparison between the
two sets of data was refined by fitting
each data set with a least squares curve
to obtain an average $/kW project cost
as a function of unit size. The data set
was then collectively used to generate
an average least-squares curve fit. The
least squares curve fit was based upon
an average of the SCR retrofit projects.
Retrofit difficulties associated with an
SCR may result in capital cost increases
of 30 to 50 percent over the base model.
The least squares curve fits were based
upon the following assumptions:
Retrofit Factor =1; Gross Heat Rate =
9880; SO2 Rate = < 3 lb/MMBtu; Type
of Coal = Bituminous; Project Execution
= Multiple lump sum contracts.’’ 150
149 https://www.epa.gov/airmarkets/progsregs/epaipm/docs/v410/Appendix52A.pdf.
150 Sargent & Lundy, ‘‘IPM Model—Revisions to
Cost and Performance for APC Technologies—SCR
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Therefore, the IPM algorithm is based
upon actual retrofit projects. As such,
the average or typical retrofit found for
the retrofit projects evaluated is
assumed to use a retrofit factor of 1.0,
and for more difficult than average
retrofits, a retrofit factor greater than 1.0
would apply. On page 1 of the
documentation of the IPM model for
SCR, it states that ‘‘Retrofit difficulties
associated with an SCR may result in
capital cost increases of 30 to 50% over
the base model.’’ Therefore, EPA
expects that retrofit difficulty factors
may apply up to around 1.50 at the
maximum. In effect, project elements
that are typically included in an SCR
retrofit are accounted for in the cost
estimated by the algorithm, and
deviations from those typical costs can
be addressed by a retrofit factor. In fact,
the algorithm expressly calls for a
retrofit factor that can be varied (see
Table 1 of reference, variable ‘‘B’’),
which makes it consistent with the
retrofit difficulty factor method called
for in the CCM. And, because the IPM
algorithm is based upon actual projects,
it already incorporates contingency.
Finally, the IPM algorithm can be
modified for other effects, such as
elevation, and EPA has since examined
this and modified its estimates in this
final action to correct for the effects of
altitude.
Comment: One commenter alleged
that site elevation was not reasonably
accounted for in EPA’s cost estimates,
particularly for PacifiCorp’s Naughton
Units 1 and 2 and Dave Johnston Unit
3. The commenter explained that
algorithms in the IPM model were
developed for a generic coal-fired power
plant located at or near sea level.
However, site elevation can have a
significant impact on control system
sizing and design. Thus, elevation of the
site must be considered separately and
factored into the unit capacity (i.e.
megawatts) accordingly due to its effects
on the flue gas volume. The commenter
pointed out that PacifiCorp’s Wyoming
BART units are located at elevations
ranging from approximately 5,000 to
7,000 feet above mean sea level. At this
elevation, flue gas flows will be 20–30
percent higher than similarly sized units
at mean sea level. The higher flue gas
flow requires larger ductwork, larger
reactors, and more robust support
structures, and these items have a
profound influence on the overall
project cost. While Wyoming had this
information available in its SIP, EPA
failed to account for site elevation in its
FIP.
Cost Development Methodology, FINAL’’, August
2010.
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Response: EPA agrees with
commenter that higher altitudes will
increase the volume of flue gas, making
it necessary to increase the crosssectional area of associated ductwork
and the SCR reactor. Increased flue gas
volume also impacts the fan design.
Consequently, EPA has revised its cost
calculations for SCR in this final action
to address issues associated with plant
altitude. While altitude has a significant
impact on the cost of SCR, it does not
make a significant difference in the cost
of SNCR because altitude does not affect
the urea flow rate or the associated urea
storage system, urea circulation system,
or metering/mixing/pumping systems.
There may be a slight increase in the
number of injectors due to increased
furnace cross-section, but this is
expected to be a small part of the total
cost of an SNCR system.
Comment: The same commenter
argued that site configurations were not
reasonably accounted for in EPA’s cost
estimates, particularly for the Naughton
Units 1 and 2 and Dave Johnston Unit
3. The IPM model applies a retrofit
factor to account for the difficulty of
fitting new BART equipment into the
existing site configuration. The Andover
Report states that site visits were not
possible. Thus, retrofit factors for
Naughton Units 1 and 2, and Dave
Johnston Unit 3 were determined based
on a review of Google EarthTM images of
the station. Accordingly, the Andover
Report applied retrofit factors for the
units that are highly subjective based on
minimal site information. The
commenter argued that, when preparing
site-specific cost estimates, site visits
must be conducted to evaluate the true
complexity associated with the retrofit
and to assess specific modifications to
the plant that would be required to
overcome issues associated with
congestion, as well as difficulties
associated with construction. Neither
Andover nor EPA sought permission
from PacifiCorp to visit the sites of the
BART units, nor did Andover explain
why it ‘‘wasn’t possible’’ to do so. Both
Sargent & Lundy and Babcock and
Wilcox have extensive experience with
PacifiCorp’s Naughton and Dave
Johnston facilities. Just since 2005,
Sargent & Lundy has been contracted by
PacifiCorp to perform 14 projects at
Dave Johnston station and over 25
projects at Naughton station. These
projects range from site evaluations,
studies, detailed engineering, or
functioning as PacifiCorp’s Owner’s
Engineer for major environmental
retrofit engineer, procure, and construct
projects. From having conducted many
site visits at these stations, Sargent &
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Lundy is very aware of site-specific
congestion and construction challenges
that would affect SCR installations at
Naughton Units 1 and 2 and Dave
Johnston Unit 3. Similar to Sargent &
Lundy’s site-specific experience,
Babcock and Wilcox has recently
completed major environmental retrofit
projects on Naughton Units 1 and 2 (wet
scrubber additions) and Dave Johnston
Unit 3 (dry scrubber and baghouse
addition), making Babcock and Wilcox
uniquely positioned to offer budgetary
cost estimates for further retrofits to
those facilities with significant firsthand knowledge. While Wyoming had
much of this information available in its
SIP, EPA failed to account for this sitespecific information in its FIP.
Response: EPA disagrees with the
commenter. EPA did account for sitespecific factors when performing its cost
estimates. Because SCRs are built on or
next to the boiler structure, they are
often elevated, and there is usually
equipment in one direction (the boiler)
or the other (other air pollution control
equipment, like an electrostatic
precipitator (ESP), scrubber, or
chimney) that limits access. This issue
is complicated further with boilers that
are located adjacent to one another—a
common configuration. Due to the
height of the SCR, large cranes play a
vital role in their construction. The
location of cranes next to where the SCR
is going to be built can be difficult.
As noted in a paper by Babcock &
Wilcox,151 key issues for SCR
constructability are site access and
ability to locate a crane and the
resulting erection sequence. The
erection sequence is impacted by the
crane that is available and whether it
can fit on site because the crane and its
location will limit the size of material
that can be lifted into place. A larger
crane allows for the lifting of larger
pieces of ductwork, resulting in fewer
lifts and less fabrication in the air.
Without adequate access for a crane and
proximity to a lay-down area for
material, erection must be done with
smaller pieces, which will require more
labor and expense.
Access around and between the
boilers will determine crane location
and location of material receiving areas.
In some cases, it may be necessary to
demolish equipment or buildings in
order to gain adequate access. In other
cases, it may be necessary or preferable
to erect cranes on the top of the boiler
structure (as was performed for the SCR
151 Hines, J.A., Kokkinos, A., Fedock, D.,
‘‘Benefits of SCR Design for Constructability’’,
Power Gen, International 2001, December 11–13,
2001, Las Vegas
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installed at Dominion’s Brayton Point
Unit 3).152
Because of its easy availability and it
usefulness in providing a ‘‘bird’s eye’’
view of the site congestion (how close
equipment is located to each other,
room for a crane, etc.), site access, local
transportation options, availability of a
lay-down area to locate material on site,
and other limitations around the site,
satellite imagery has become a very
important tool in evaluating these sitespecific factors. In fact, the major air
pollution control original equipment
manufacturers use satellite imagery to
assist them in estimating site congestion
issues, determining location of
construction equipment and other
limitations on and around the site in
this way. Site visits are also useful, but
are normally performed in addition to
rather than in lieu of careful
examination of satellite images. For
example, in their comments to EPA in
2010, the Utility Air Regulatory Group
used satellite photographs to
demonstrate the relative difficulty of
different SCR installations.153
While a site visit can be useful and
provide additional information,
assessing satellite imagery provides
adequate information to determine
access to the site, access around the
boilers, availability of space for locating
construction equipment and materials,
and whether buildings or equipment
must be demolished to make room for
the equipment. Notably, the budgetary
price provided to PacifiCorp from
Babcock & Wilcox was not developed
from a site visit. Per the cover page of
the budgetary proposal, ‘‘[g]iven the
budgetary nature of this request, we
have not made site visits to consider
layout options: instead, we have used
available drawings and made necessary
assumptions to enable us to establish a
basis to derive quantities of material and
associated costs.’’
For SCR installations, site visits and
more detailed boiler drawings provide
additional information regarding air
preheater location and whether it must
be relocated to make room for the SCR,
or if ductwork limitations require
demolition of other large pieces of
equipment such as ESPs. Such costs
will significantly increase the cost of
retrofitting an SCR. However, relocation
of the air preheater or ESP was not
identified as a concern by any of the
commenters. Instead, most commenters
152 Wright, B., Erickson, C., Phillipo, M., ‘‘Keys to
Success: SCR Installations at Dominions Brayton
Point Units 1 and 3’’, Electric Power, May 2008.
153 Cichanowicz, E., ‘‘Current Capital Cost and
Cost-Effectiveness of Power Plant Emissions Control
Technologies’’, Prepared for Utility Air Regulatory
Group, January 2010.
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raised retrofit issues that are commonly
encountered in SCR retrofits, including
location of SCR support steel and
possible interferences with other
equipment on site; penetration of boiler
building by SCR ductwork; location of
cranes for units that are side-by-side; the
need for increased fan capacity and
associated electrical modifications; and
stiffening of ductwork due to increased
pressure drop from SCR. As a result, the
retrofit costs in the IPM algorithms that
were developed from actual SCR
projects should capture these more
common retrofit issues and to the extent
that some situations seem more
difficult, can be addressed with retrofit
factors.
In its cost estimates, PacifiCorp
provided a long comparative table (over
100 rows with 25 columns of data) for
Dave Johnston 3 and Naughton 1 and 2
showing different cost estimating
methods. The table showed vendor
budgetary pricing for Direct Capital
Costs based upon a proposal from
Babcock & Wilcox. While EPA accepts
the proposal from Babcock & Wilcox as
part of our final action, we have a few
general comments. The proposal, while
providing a detailed total scope of
supply, provides a total cost for the
project without line items. In addition,
the items included under the Owner’s
scope by Black and Veatch are limited
to: Boiler modifications; air-preheater
modifications; medium voltage power
source; asbestos, lead, and
polychlorinated biphenyls (PCB)
remediation; commercial licenses and
permits; and spare parts. Some of these
costs, such as air-preheater
modifications, will not be required,
while others will have a small to modest
impact on the overall cost. Notably, the
cost estimate includes items like potable
water systems, fire protection, service
water, other assorted auxiliaries, as well
as roads, fences, etc. Therefore, the
proposal is close to being ‘‘turnkey’’ and
includes nearly all costs for the project.
It also includes some items that would
fall into the category of General
Facilities. The proposal assumes that
other modifications to the Naughton
plant will result in abandonment of
existing chimneys and ESPs on Units 1
and 2. Currently, these chimneys are in
service. Babcock & Wilcox also
determined that the existing fans are
likely to be sufficient for the additional
draft loss from the SCR. As was noted
in the Andover Report, we think that
there may be some substantial
conservatism built into the Babcock and
Wilcox estimate. For example, the
proposal states that the offset of
Naughton Units 1 and 2 is just enough
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to make it impractical to make a
common structure for both SCR reactors.
However, examination of the drawings
in the proposal shows that Babcock &
Wilcox has sized the ductwork to
compensate for the offset so that the
SCR reactors should be able to be
supported with a common structure.
Also, the proposal assumes that the
abandoned stacks at both sites will be
dismantled, although this does not
appear to be necessary for Naughton
Unit 2 and may not be necessary for
Dave Johnston Unit 3 if shorter
horizontal duct runs are used. Finally,
comparison of the cost estimate
provided by PacifiCorp for Naughton
Unit 1 and 2, and Naughton 1
especially, to historical costs shows that
the costs are well in excess of what
other SCRs have cost. This is
particularly perplexing because
additional fan capacity is not needed,
and it is not necessary to move the air
preheater.
In light of the proposal and its fairly
comprehensive scope of supply,
PacifiCorp’s capital cost estimate
included a number of items that EPA is
not including in our cost estimate, as
noted below:
1. Process Contingency: Although the
CCM permits a process contingency of
5%, in EPA’s opinion this is not
necessary today for SCR on coal-fired
boilers firing the coals used in
Wyoming. According to the Department
of Energy’s National Energy Technology
Laboratory,154 ‘‘Process contingency is
intended to compensate for uncertainty
in cost estimates caused by performance
uncertainties associated with the
development status of a technology.
Process contingencies are applied to
each plant section based on its current
technology status.’’ According to the
document, for commercially available
technologies, process contingency could
range from 0–10%.
When the CCM was issued in January
2002, SCR was commercially available
but was only emerging in application on
coal-fired utility boilers in the U.S.
According to a study by
Cichanowicz,155 there was only about
13,000 MW of coal-fired capacity using
SCR in the U.S. at the end of 2001, with
nearly all SCRs installed in the prior
two years, meaning that there was very
limited long-term experience with SCR
on coal-fired units. SCR usage on coal154 U.S.
Department of Energy, National Energy
Technology Laboratory, ‘‘Cost Estimating
Methodology for NETL Assessments of Power Plant
Performance’’, DOE/NETL–2011/1455, April 2011,
pg 4.
155 From data in Cichanowicz, J., Muzio, L., Hein,
M., ‘‘The First 100 GW of SCR in the U.S.,—What
Have We Learned?’’—2006 Mega Symposium.
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fired boilers has since increased about
ten-fold to about 130,000 MW of coal
capacity (over 40% of all U.S. coal
capacity), and is therefore a very well
proven and well understood technology
on a wide range of U.S. coals, including
Powder River Basin coal. As a result, the
process contingency for SCR on coalfired utility boilers should be much
lower today than what it was when the
CCM was issued in January 2002, which
was 5%. EPA believes that for SCR
applications on utility boilers burning
Powder River Basin coals (the Wyoming
utility boilers), which are very well
understood SCR applications, there
should not be any need for process
contingency.
2. Project Contingency: Because the
cost estimates developed for PacifiCorp
are already very conservative and based
upon detailed estimates of the labor and
materials to build the SCR, a 15%
project contingency is excessive.
According to the CCM at Section 1.1,
Chapter 1, pages 1–4: ‘‘The accuracy of
the information in the Manual works at
two distinct levels. From a regulatory
standpoint, the Manual estimating
procedure rests on the notion of the
‘‘study’’ (or rough order of magnitude—
ROM) estimate, nominally accurate to
within ± 30%. This type of estimate is
well suited to estimating control system
costs intended for use in regulatory
development because they do not
require detailed site-specific
information necessary for industry level
analyses.’’
The methods and cost elements of the
CCM were adapted from the American
Association of Cost Engineers, or AACE
(CCM Section 1, Chapter 2, pages 2–5).
AACE 16R–90 156 states that, ‘‘Project
Contingency is included to cover the
costs that would result if a detailed-type
costing was followed as in a definitivetype study.’’ According to National
Energy Technology Laboratory (NETL),
‘‘AACE 16R–90 states that project
contingency for a ‘budget-type’ estimate
(AACE Class 4 or 5) should be 15% to
30% of the sum of [bare erected cost],
[engineering, procurement, and
construction] fees and process
contingency.’’ 157 AACE 18R–97 defines
different classes of estimates, from Class
5 (least detailed) to Class 1 (most
detailed).158 The methodology used in
the CCM falls into a Class 4 or Class 5,
156 AACE Recommended Practice, AACE 16R–90;
www.aacei.org/non/rps/18R-90.pdf.
157 U.S. Department of Energy, National Energy
Technology Laboratory, ‘‘Cost Estimating
Methodology for NETL Assessments of Power Plant
Performance’’, DOE/NETL–2011/1455, April 2011,
pg 5.
158 AACE Recommended Practice, AACE 16R–87;
www.aacei.org/non/rps/18R-97.pdf.
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while the methodology used by
PacifiCorp’s contractor, Babcock and
Wilcox, is clearly a far more detailed
estimate that does not leave out any
aspect of the project. Therefore, the
project contingency factor is not
applicable. The 15% project
contingency factor in the CCM for SCR
is based upon use of the cost-estimating
method described in the CCM to
develop the Total Direct Capital Costs.
It is not intended to apply to a detailed
estimate that:
• Includes many cost items not
explicitly included in the estimating
method described in the CCM to
develop the Total Direct Capital Costs
and meant to be included in the 15%
project contingency; and
• Already has substantial contingency
built into it through conservative
assumptions.
In fact, the CCM discusses the
importance of not double-counting
contingency in multiple places, such as
retrofit factor and contingency: ‘‘Due to
the uncertain nature of many estimates,
analysts may want to add an additional
contingency (i.e., uncertainty) factor to
their estimate. However, the retrofit
factor is a kind of contingency factor
and the cost analyst must be careful to
not impose a double penalty on the
system for the same unforeseen
conditions. Retrofit factors should be
reserved for those items directly related
to the demolition, fabrication, and
installation of the control system. A
contingency factor should be reserved
(and applied to) only those items that
could incur a reasonable but
unanticipated increase but are not
directly related to the demolition,
fabrication, and installation of the
system. For example, a hundred year
flood may postpone delivery of
materials, but their arrival at the job site
is not a problem unique to a retrofit
situation.’’ (emphasis added). The CCM,
therefore, explicitly anticipates that
some analysts may, incorrectly, apply
multiple contingencies for the same
areas of uncertainty even when using
the methods described in the CCM for
estimating Total Direct Capital Costs.
Because the cost estimates developed
for PacifiCorp are already very
conservative and based upon detailed
estimates of the labor and materials to
build the SCR, rather than study-level
estimates, they have double-counted
both the costs that are intended by the
CCM to be included in the project
contingency when using the CCM
method, plus they have added
additional contingency in the form of
conservative assumptions to address
uncertainties in their estimate. For this
reason, a 15% project contingency is
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excessive, and we have not revised our
cost estimates to include one.
3. General Facilities: The cost
estimate from Babcock & Wilcox,
submitted by PacifiCorp, includes
several items that would fall into the
category of General Facilities, and in
order to avoid double-counting, EPA has
not included an additional line item for
General Facilities.
Comment: The same commenter
suggested that the project-specific
scopes were not reasonably accounted
for in EPA’s cost estimates, particularly
for Naughton Units 1 and 2 and Dave
Johnston Unit 3. Additional projectspecific scope concerns (related to the
addition of SCR on-site) include limited
capacity of the existing induced-draft
fans and auxiliary power system, as well
as National Fire Protection Associationrelated equipment reinforcement
requirements. Larger, more powerful,
induced-draft fans may overload
existing electrical systems, and the
electrical systems may require
significant modifications. Structural
stiffening of the duct work, and
equipment downstream of the boiler
and upstream of the new fans may also
be required by National Fire Protection
Association regulations to operate at
more negative pressures due to the
installation of the SCR. These types of
costs are not generally reflected in the
base case IPM cost algorithms, but they
must be taken into consideration in the
development of a project-specific cost
estimate. Wyoming had this information
available in the Wyoming SIP, but EPA
failed to account for this important cost
information in its FIP.
Response: All SCR systems
experience a pressure drop across the
SCR, and therefore some consideration
must be made to fan capacity for every
SCR system. The algorithm used by EPA
explicitly includes a ‘‘balance of plant’’
cost line item such as an allowance for
additional fans and auxiliary electrical
work.159 As for the duct stiffening, this
is frequently necessary when new fans
are installed. However, as noted in the
proposal by Babcock & Wilcox,
additional fan capacity is not expected
to be necessary at Naughton Units 1 and
2 or Dave Johnston Unit 3.
Comment: The same commenter
alleged that Owner’s costs were not
reasonably accounted for in EPA’s cost
estimates, particularly for Naughton
Units 1 and 2 and Dave Johnston Unit
3. Owner’s Costs include a variety of
non-financial costs incurred by the
159 Sargent & Lundy, ‘‘IPM Model—Revisions to
Cost and Performance for APC Technologies—SCR
Cost Development Methodology, FINAL’’, August
2010, Table 1, pg. 5.
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owner to support implementation of the
air pollution control project. Owner’s
Costs are project-specific, but generally
include costs incurred by the owner to
manage the project, hire and retain staff
to support the project, and costs
associated with third party assistance
associated with project development
and financing. Owner’s Costs are real
costs that the owner will incur during
the project and are typically included in
cost estimates prepared for large air
pollution control retrofit projects. In
fact, EPA’s Coal Quality Environmental
Cost (CUECost) model includes Owner’s
Costs (or ‘‘Home Office’’ costs) in its air
pollution control system cost estimating
workbook and interrelated set of
spreadsheets. See CUECost Workbook
User’s Manual Version 1.0, prepared by
Raytheon Engineers & Contractors, Inc.
and Eastern Research Group, Inc., EPA
Contract No. 68–D7–0001, Appendix B,
pages B–3 and B–6. Wyoming had this
information available in its SIP, but EPA
failed to account for this important cost
information in its FIP.
Response: Home office fees are
Owner’s costs, and these are accounted
for in the CCM in the 10% allowance for
Engineering and Owner’s Costs. See
CCM at Section 4.2, Chapter 2, page 2–
44). As described in Table 2.5 of the
CCM, engineering and home office fees
represent 10% of purchased equipment
costs. In this respect, we agree with the
commenter’s assertions that the CCM
does discuss some of the items that roll
up into these line items. For example,
the CCM does provide for ‘‘Engineering
and Home Office Fees’’ that includes the
home office and plant support costs
described in the comments. We have
included the portion of Owner’s Costs/
Surcharge in the total cost, up to the
value specified for ‘‘Engineering and
Home Office Fees’’ indicated by the
CCM, which is 10%.
The cost factors used in the CCM
include home office fees in the 10% that
is applied to engineering fees; however,
the line item for Owner’s Cost in the
IPM estimate was made zero. The reason
Owners Cost was removed is that the
CCM includes owner’s cost with the
10% for engineering and home office
fees. A 10% engineering charge was
already applied and therefore an
additional allowance for home office
fees would be greater than the cost
allowed under the CCM. Even if that
cost were added at a 5% rate, it would
increase capital cost by 5%. This
difference would not change the
determination.
Comment: The same commenter
argued that regional labor concerns were
not reasonably accounted for in EPA’s
cost estimates, particularly for Naughton
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Units 1 and 2 and Dave Johnston Unit
3. Regional labor concerns are not
accounted for in the IPM model.
Regional labor characteristics must be
taken into consideration in a sitespecific cost estimate to account for
factors including labor availability,
project complexity, local climate, and
working conditions. Because the
Naughton and Dave Johnston facilities
are in relatively remote locations, higher
labor rates must be paid to attract the
kind of skilled workers required to
construct an SCR project. In addition,
the locations are subject to extreme cold
and wind that can result in significant
productivity and construction
challenges and delays, adding to the
overall project cost. Wyoming had this
information available in its SIP, but EPA
failed to account for this important cost
information in its FIP.
EPA’s flawed analyses of incomplete
‘‘new’’ cost information directly
resulted in EPA’s proposed
requirements for PacifiCorp to install
SCR on Naughton Units 1 and 2 and
Dave Johnston Unit 3. In contrast, to be
responsive to EPA’s request for
additional information, PacifiCorp has
solicited budgetary project-specific cost
information from Babcock and Wilcox,
an active and uniquely positioned
competitive market participant for SCR
technology, for these same units. In
conjunction with Sargent & Lundy’s
expertise, PacifiCorp has incorporated
the site-specific budgetary cost
information from Babcock and Wilcox
into updated EPA CCM side-by-side
comparisons with the Andover Report
results to further demonstrate the
inaccuracies in the new cost
information developed by EPA. (The
following included tables to summarize
the results of these comparisons.) It is
important to note that PacifiCorp has
utilized a 20-year remaining equipment
life and has excluded AFUDC from the
results in the tables for comparison
purposes.
As demonstrated by the results in the
tables, EPA significantly understated
costs per ton of pollutant removed. As
such, EPA based its cost-effectiveness
conclusions on significantly inaccurate
information. Before taking any final
action on the proposed FIP, EPA must
consider in its final BART analyses the
additional cost information being
provided by PacifiCorp.
Response: EPA disagrees with this
comment. The commenter claims that
remote locations require offering higher
wage rates and that conditions at the
site, including inclement weather,
reduce worker productivity. Because the
commenter claims that these are
important factors that impact cost, the
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commenter should have provided data
to support its assertions. The
commenter did not provide any data to
demonstrate that wage rates in the area
near its facilities are higher than in more
populated areas. The commenter also
did not provide any specific
productivity factors or other evidence to
show how the commenter arrived at its
man-hour estimates or explain how
those estimates differ from a normal
productivity. Without such information,
EPA cannot review and validate the
commenter’s claims that labor
productivity is low or that labor cost is
high.
On the other hand, labor rates for
union construction labor are available
from the Construction Labor Research
Council (CLRC),160 and these rates are
consistently well below what appears to
have been assumed in the itemized
estimate provided with Basin Electric’s
comments. The difference is too large to
be explained by per diem. Because both
Basin Electric and PacifiCorp used
Sargent & Lundy to prepare their cost
estimates, it is reasonable to assume that
both companies have made similar
assumptions. Moreover, in addition to
the high labor rates assumed, there are
additional line item costs for overtime
and per diem. As a result, the estimates
provided by commenters appears to
incorporate additional costs or
provisions well beyond the normal costs
both in the labor rates and in the line
item for additional labor costs.
While EPA welcomes the use of SCR
vendor estimates, such as those used by
PacifiCorp, or engineering estimates,
such as those provided by Basin
Electric, specific details supporting the
estimates must be provided in order for
them to be useful. Without details on
the scope of supply, the estimates
cannot be used as a reliable source of
information because vendor scope could
potentially be in error or could be
duplicative of other costs included in
the estimate elsewhere.
With regard to adjustment for regional
labor concerns, neither PacifiCorp nor
Basin Electric’s submittals were
satisfactory. Deficiencies in Basin
Electric’s submittal with regard to
regional labor concerns are addressed
elsewhere in these responses to
comments. The proposal from Babcock
& Wilcox, while showing a total lump
sum price, did not demonstrate how
they factored in regional labor concerns.
Comment: The IPM methodology
relied upon in the Andover Report is
160 Construction Labor Research Council Union
Wages and Supplements, available from the
National Construction Boilermaker Employers Web
site, www.nacbe.com.
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inconsistent with the assumptions set
forth in the CCM. While EPA states that
its revised cost analyses ‘‘followed the
structure of the EPA CCM,’’ EPA
acknowledges that ‘‘we have largely
used the Integrated Planning Model cost
calculations to estimate direct capital
costs and operating and maintenance
costs.’’ 78 FR 34749. See also Andover
Update (‘‘In estimating the costs of
controls, the following were considered:
IPM Cost Models, US EPA Air Pollution
CCM.’’). The IPM model is a regulatory
model that uses cost algorithms
developed by Sargent & Lundy to
estimate system-wide costs of air
pollution technology for adoption of
national regulations. The inputs in the
IPM model do not conform to the
methodology set forth in the CCM, and
neither Andover nor EPA offers any
explanation for the discrepancies. This
failure epitomizes the arbitrary and
capricious nature of EPA’s decision
making.
A careful reading of the Andover
Report evidences that Andover only
followed the CCM on a limited basis,
and in doing so, read into the CCM
requirements that are non-existent,
while ignoring wholesale many of the
CCM’s recommendations. The following
language from the report illustrates the
concern: ‘‘The BART Guidelines
recommend use of the EPA Air
Pollution CCM, and the methodology
used here for estimating costs is
consistent with the recommendations in
the manual, such as inclusion of taxes,
insurance and administrative costs, and
the use of overnight cost for capital
cost.’’
As an initial matter, the CCM does not
anywhere recommend the use of
‘‘overnight cost’’ for estimating capital
costs. See Section XI.B.3. The overnight
approach assumes construction of a
project ‘‘overnight,’’ which means a
party would not incur any interest
charges, including AFUDC, or
experience any cost escalations. While a
‘‘constant dollar approach’’ may be read
to exclude escalation, the CCM does not
recommend that users assume that the
interest costs related to constructing a
capital-intensive, multi-year project will
cost the same as an off-the-shelf control
technology that can be installed in a
day. Furthermore, based on the
acknowledgment in its report, Andover
appears only to have followed the
methodology set forth in the CCM in
these three limited respects. In all other
respects, Andover relied on the IPM cost
algorithms for its SCR estimate, without
regard to the CCM. For SNCR capital
costs, Andover relied on an assumed
$20/kW cost rather than using the IPM
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algorithms or the methodology set forth
in the CCM.
The high-level cost algorithms in the
IPM model and the assumed $20/kW
capital cost for SNCR resulted in a
substantial underestimate of the costs of
designing and constructing both the
SCR and SNCR systems. For example,
the only inputs to the IPM cost modules
are unit size, heat input, fuel type, and
NOX removal efficiency. The CCM uses
these inputs, but also provides for using
SCR design parameters, such as flue gas
flow rate, actual stoichiometric ratio
(the amount of reagent needed to
achieve target NOX emissions), space
velocity and area velocity (a measure of
flue gas resident time in the SCR
reactor), catalyst volume, SCR reactor
dimensions, and reagent consumption.
The CCM methodology includes similar
design parameters specific to SNCR,
which the IPM model does not include
and which Andover did not consider in
its cost estimate.
Andover also used the IPM model to
calculate indirect capital costs in the
SCR cost estimate. The IPM model
includes in its indirect capital cost
algorithm factors for Engineering and
Construction Management, Labor, and
Contractor Profit/Fees. Andover
removed from the IPM capital cost
calculation both Owner’s Costs and
AFUDC. Moreover, the IPM Model does
not include a number of other inputs
that are included in the CCM, including
preproduction costs, inventory capital,
and initial catalyst costs, and Andover
did not adjust the model to incorporate
these additional costs. Andover’s
selection of certain IPM model inputs
and exclusion of inputs in the CCM
resulted in the substantial
underestimation of the indirect capital
costs necessary to design and install an
SCR system.
For SNCR, Andover arbitrarily
assigned a capital cost of $20/kW,
without using the IPM algorithms or
performing an analysis of direct and
indirect costs consistent with the CCM.
Andover relied on the IPM model to
calculate operating and maintenance
costs except for urea reagent costs for
SNCR, which uses factors that differ
from those recommended in the CCM
and costs utilized by Sargent & Lundy.
The model’s simplistic treatment of
catalyst costs, for example, is
inconsistent with the recommendations
in the CCM and underestimates annual
catalyst replacement costs for SCR and
for SNCR. For SNCR, Andover adjusted
the urea utilization rate from the IPM
model without explanation, which cut
in half estimated annual urea costs.
Andover also assumed urea would be
used as the reagent for SCR, which
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increased reagent costs above those
calculated by Sargent & Lundy based on
the use of anhydrous ammonia.
Neither Andover nor EPA explains
why the cost estimate uses only limited
portions of the CCM, or why Andover
believes use of the IPM cost
methodology is somehow more
representative of the costs of control
that would be incurred by Basin Electric
for installation of SCR and SNCR
systems. It is inherently contradictory,
and therefore arbitrary and capricious,
for EPA to base its proposed disapproval
of Laramie River BART on the alleged
failures of Wyoming to follow the CCM,
while at the same time relying on a
consultant’s report that does not comply
with those same standards.
Response: EPA disagrees with the
commenter. The methodology used by
EPA is consistent with the CCM for the
following reasons: (1) EPA used the
overnight cost method, which excludes
certain cost elements such as AFUDC;
(2) The comparative nature of BART
costs makes use of the IPM algorithms
a reasonable approach; and (3) as
demonstrated in the Exhibit 14 of Basin
Electric’s comments, use of the cost
equations in the CCM would have
actually resulted in lower costs than
predicted by the IPM algorithms.
Moreover, both the IPM algorithms
and Sargent & Lundy’s estimates for
Basin Electric are empirically based
from data collected at other projects.
According to page 21 of Exhibit 14 to
Basin Electric’s comments: ‘‘. . . Cost
estimates prepared for LRS are based on
equipment costs and budgetary quotes
available from similar projects and
Sargent & Lundy’s experience with the
design and installation of retrofit SNCR
and SCR control systems. The LRS cost
estimates are conceptual in nature; thus,
Sargent & Lundy did not procure
equipment quotes specifically for the
LRS control systems. Rather, equipment
costs for the LRS projects are based on
conceptual designs developed for the
control systems, preliminary equipment
sizing developed for the major pieces of
equipment, and recent pricing for
similar equipment . . .’’ As a result, the
estimates provided by Basin Electric are
not more valid than those developed by
EPA.
Commenter claims that AFUDC
should be included in the cost analysis.
As described in our responses to other
comments, the CCM explicitly excludes
AFUDC from control costs, and EPA’s
estimates were correct in excluding
AFUDC. This is central to the overnight
cost methodology.
Commenter is critical of EPA’s
method for estimating SNCR capital
cost. With regard to SNCR cost
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methodology, the cost of SNCR is driven
primarily by the operating cost. Capital
cost has a small effect on total cost of
SNCR. Therefore, a simplifying
assumption that yields a reasonable
estimate of capital cost will result in an
annualized cost accurate to within ±
30%. Based upon input from technology
vendors on cost for other units 161 and
based upon the fact that EPA’s
contractor Andover has over 25 years of
direct experience designing, specifying
and optimizing SNCR systems, $20/kW
was a very reasonable estimate. EPA’s
contractor also reviewed the SNCR
algorithms developed by Sargent &
Lundy for EPA and is of the opinion
that in most cases $20/kW provides a
better estimate than the IPM algorithm
because the IPM algorithm assumes
greater economies of scale than
generally exist in SNCR applications.
On the other hand, as will be
described later in this response, the high
reported furnace temperature at Basin
Electric’s Laramie River Station means
that SNCR will require a more complex
injection system and will have a higher
urea injection rate than what is typical
for most SNCR systems. For this reason
EPA has accepted the capital cost of
SNCR estimate provided by Basin
Electric. In any event, SNCR capital cost
generally has a small effect on cost
compared to operating cost.
Commenter is critical of EPA’s use of
the IPM algorithm as not utilizing the
same input design parameters. As
described in other responses to
comments, the IPM algorithm for SCR
incorporates either directly or by
inference all of the inputs the
commenter has raised. But, commenter
is incorrect about some of the claimed
inputs. Stoichiometric ratio, space
velocity, area velocity, catalyst volume,
SCR reactor volume, and reagent
consumption are not inputs to an SCR
design, but are all direct results of
design calculations using the inputs of
initial NOX level, final NOX level (and
by inference percent reduction), unit
size, heat rate, and fuel characteristics—
all inputs to the IPM model. Gas flow
rate is also normally calculated based
upon fuel type, unit size and heat rate—
again, IPM inputs. The IPM model
therefore directly develops SCR reactor
cost based upon all of the same inputs,
but using algorithms based upon a
database of the cost of actually
constructed units. Other costs, such as
preproduction costs and initial
inventory of ammonia are incorporated
into the capital costs. In any event, these
161 Email from Alex Dainoff, Fuel Tech, to James
Staudt, Andover Technology Partners, Wednesday,
June 27, 2012.
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5143
are very small portions of total cost.
Initial catalyst cost is incorporated into
the direct capital costs of the project in
the IPM estimate, and in any event,
initial catalyst cost is typically a very
small portion of total capital cost.
Commenter is critical of EPA’s
treatment of the associated costs for
replacement catalyst. Regarding
treatment of catalyst cost, EPA’s
approach is reasonable, factoring in the
NOX reduction, coal, facility size,
capacity factor, and catalyst cost—all of
the same factors that impact catalyst
replacement cost. PacifiCorp, on the
other hand, uses excessive catalyst
replacement costs. PacifiCorp’s use of
$290/ft3 for replacement catalyst cost
equates to $10,422/m3. This is nearly
double the current cost of new catalyst.
The difference cannot be accounted for
in the labor to install catalyst, which is
a very small fraction of the catalyst
cost.162 Moreover, replacement catalyst
is frequently regenerated catalyst which
costs roughly half the cost of new
catalyst. EPA conservatively assumed
new catalyst at roughly $5,500/m3,163
when in fact most catalyst
replenishments will likely be at a much
lower cost due to the extensive
availability of regenerated catalyst. As a
result, EPA’s catalyst costs are much
more reasonable and are in fact,
conservative in light of the availability
of regenerated catalyst.
Commenters are critical of EPA’s
estimates of SNCR reagent consumption.
Because of the importance of reagent
consumption on SNCR system capital
and operating cost, chemical utilization
is an important factor. Utilization is a
measure of how efficiently the SNCR
reagent reduces NOX. With SNCR, NOX
reduction does not occur on a one-forone basis as reagent is added because a
portion of the chemical introduced does
not contribute to NOX reduction. The
utilization of reagent (normally urea)
declines as temperature (or carbon
monoxide concentration) increases
because more of the urea becomes
oxidized (forming NOX), which reduces
the amount of reagent available for the
NOX reduction reaction. The net
difference between the amount of NOX
reduced and the amount of NOX formed
equals the overall reduction in NOX,
and at a sufficiently high temperature,
NOX can actually increase as urea is
injected. Hence, furnace temperature is
162 From data in Cichanowicz, J., Muzio, L., Hein,
M., ‘‘The First 100 GW of SCR in the U.S.,—What
Have We Learned?’’—2006 Mega Symposium, page
4.
163 Cichanowicz, J.E., ‘‘Current Capital Cost and
Cost-Effectiveness of Power Plant Emissions Control
Technologies’’ Prepared for, Utility Air Regulatory
Group, January 2010.
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a critical parameter in determining
utilization.
Chemical utilization is equal to the
percent NOX reduction divided by the
treatment rate, expressed in terms of
Normalized Stoichiometric Ratio. The
IPM model assumes a default chemical
utilization rate of 15%. Commenter
states that Andover adjusted the urea
utilization rate in the IPM model
without explanation. On the contrary,
on page 3 of its memo, Andover
provided actual utility data and
explained why 25% was a more
common utilization rate for utility
boilers. Chemical utilization is a strong
function of furnace temperature, and
because chemical consumption is the
single largest expense associated with
SNCR, using an incorrect chemical
utilization will lead to large
discrepancies in cost.
Commenter states that the furnace exit
gas temperature is 2710 °F. While EPA
suspects that this may be in error (high),
it is the data provided by the company.
If this temperature is correct, SNCR may
only be marginally effective. Sargent &
Lundy estimated a chemical utilization
of 12%, which is possibly optimistic.
Information from Fuel Tech, the leading
supplier of SNCR technology, stated that
at the unusually high furnace exit
temperature of 2500 °F, well below
2710 °F assumed by Sargent & Lundy, a
25% reduction was possible at a
particular facility from a similar NOX
baseline with a Normalized
Stoichiometric Ratio of 1.75 (utilization
of 14.3%). Hence, EPA will accept the
12% utilization and 20% NOX reduction
assumed by Sargent & Lundy for
Laramie River Station.164
The model in the IPM, which was
developed by Sargent & Lundy, assumes
a utilization rate of 15%, which
Andover’s data, as well as Fuel Tech’s
input, demonstrates is too low for most
facilities. It is therefore a very
conservative estimate of chemical
utilization. In fact, Andover reviewed
Sargent & Lundy’s model when it was
developed for EPA and Sargent & Lundy
did not provide any supporting data
regarding the assumed utilization rate at
that time. However, in light of the high
assumed furnace temperature at Laramie
River Station, EPA is assuming a 12%
chemical utilization at a 20% NOX
removal rate for those units.165
On the other hand, in the October 28,
2013 memo by Andover for EPA, test
data for utility boilers was provided
showing that 25% is a more reasonable
utilization rate for most units. Moreover,
164 Email from Alexander Dainoff to Jim Staudt,
June 27, 2012.
165 Exhibit 16 to Basin Electric comment, page 25.
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Andover’s principal has conducted
numerous electric utility SNCR
optimization programs, among them are
programs described in referenced
papers, which makes him qualified to
make this determination.166 167 168 So, in
applications where more typical furnace
temperatures are expected, a chemical
utilization rate closer to 25% can be
reasonably assumed.
It is also likely that, in light of the
higher furnace exit temperature at
Laramie River Station, it will be
necessary to utilize a more complex and
costly injection system that requires
injection of urea into convective regions
of the furnace using multiple-nozzle
lances in addition to the more typical
wall injectors. For this reason, EPA is
accepting the capital cost developed by
Sargent & Lundy for Basin Electric of
$16.9 million per unit.
Regarding the reagent used for SCR, as
the commenter points out, EPA’s initial
estimates assumed that urea would be
used as the feed reagent for SCR, which
results in a higher reagent cost than for
anhydrous ammonia. Because
commenters have indicated that
anhydrous ammonia will be used as a
reagent rather than urea, EPA’s revised
estimates assume ammonia as a reagent.
This will result in lower reagent costs.
EPA is also using anhydrous ammonia
costs provided by Potash Corporation
instead of the value provided by the
utility.169 The cost used by EPA
represents the actual delivered cost of
anhydrous ammonia, as quoted by a
major reagent supplier.
Basin Electric provided a site-specific
estimate. EPA generally supports the
use of vendor quotes and site-specific
estimates but only as used within the
parameters of the overnight cost
methodology and the CCM. The BART
Guidelines, are clear that ‘‘[y]ou should
include documentation for any
additional information you used for the
cost calculations, including any
information supplied by vendors that
166 Staudt, J., Casill, R., Tsai, T., Ariagno, L.,
‘‘Commercial Application of Urea SNCR for NOX
RACT Compliance on a 112 MWe Pulverized Coal
Boiler’’, 1995 EPRI/EPA Joint Symposium on
Stationary Combustion NOX Control, Kansas City,
May 16–19, 1995.
167 Staudt, J, Hoover, B., Trautner, P., McCool, S.,
Frey, J., ‘‘Optimization of Constellation Energy’s
SNCR System at Crane Units 1 and 2 Using
Continuous Ammonia Measurement’’, The MEGA
Symposium, Baltimore, MD, August 31–September
2, 2010.
168 Staudt, J.E., Kehrer, K., Poczynec, J., Cote, R.,
Pierce, R., Afonso, R., and Sload, A., ‘‘Optimizing
Selective Non-Catalytic Reduction Systems for CostEffective Operation on Coal-Fired Electric Utility
Boilers’’, presented at ICAC Forum ’98, Durham,
March 1998.
169 Email from Potash Corporation to Andover
Technology Partners, September 27, 2013.
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affects your assumptions regarding
purchased equipment costs, equipment
life, replacement of major components,
and any other element of the calculation
that differs from the CCM.’’ 170 When
supporting documentation to site
estimates are not provided, assumptions
based upon these cannot be considered.
Much of the documentation owners
cite to support additional costs were not
provided to us. For instance, although
Basin Electric provided a table that
listed their cost line items, this
spreadsheet (in pdf format), over 600
lines in length (and including line items
such as 4″ gravel surfacing and chain
link fence), was stripped of all cell
calculations, preventing any meaningful
review.
There was also inadequate
explanation for how man-hour rates
were developed. For example, current
union boilermaker rates for Lodge 101
(Denver) range from $57.62 per hour for
a Journeyman to $60.12 per hour for a
Foreman, with apprentices at lower
rates.171 The CLRC reports similar union
boilermaker rates in the MountainNorthern Plains area at $56.59/hr for
July 2013.172 For non-union
boilermakers, the cost is expected to be
less. Yet, for tasks that appear to be for
boilermakers (ductwork) rates of $90.79
per man-hour are used.173 This is a large
unexplained difference in cost. It may
be that part of it is per diem ($55/day
for over 70 miles and $70/day for over
120 miles per Lodge 101 information),
but per diem does not explain the full
difference. Per diem, however, is also
provided as a separate cost later in the
estimate, making the high labor rate
more difficult to explain. Some portion
may be for overtime, but there is no
explanation provided (overtime is also
added as a separate line item later in the
estimate). Without an explanation it is
not possible to evaluate these costs,
which clearly deviate from publicly
available costs for labor. In addition to
not providing the necessary required
supporting documentation, Basin
Electric did not follow the overnight
cost methodology. Thus, Basin Electric
has failed to meet the test that is
required to support deviations from the
CCM.
170 70
FR 39166, footnote 15.
& Benefit Information, Western States
Field Constructions Bargaining Agreement,
Effective January 1, 2013 through September 31,
2013.
172 Construction Labor Research Council Union
Wages and Supplements for the Period 07/01/2008–
07/01/2013. Available from the National
Association of Construction Boilermaker Employers
Web site: www.nacbe.org.
173 Appendices to Exhibit 14. Page 6 of SCR
estimate (pdf page 43).
171 Wage
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Comment: The IPM methodology
relied upon in the Andover Report is
inconsistent with the BART Guidelines.
The Guidelines require that to conduct
a cost analysis, a state must ‘‘[i]dentify
parameters’’ for emission control and
then ‘‘[d]evelop cost estimates based
upon those design parameters.’’ 70 FR
39166. The cost analysis includes
development of ‘‘estimates of capital
and annual costs,’’ based on the CCM
‘‘where possible,’’ but ‘‘tak[ing] into
account any site-specific design or other
conditions identified above that affect
the cost of a particular BART technology
option.’’ Id. Andover failed to adhere to
the methodology set forth in the CCM
‘‘where possible.’’ More importantly,
however, Andover neither followed the
three-step process in the BART
Guidelines for estimating costs of
compliance nor appropriately
considered the critical site- and projectspecific variables that affect the cost of
both SCR and SNCR at Laramie River.
EPA’s failure to comply with its own
Guidelines results in an inaccurate cost
estimate that should not form the basis
of a BART determination.
Response: EPA disagrees with the
commenter. The three step process was
followed for all cost estimates for
affected Wyoming units. The three-step
process requires that states (or EPA): (1)
Identify the emissions units being
controlled; (2) Identify design
parameters for emission controls; and
(3) Develop cost estimates based upon
those design parameters. The BART
affected units were already identified by
the State and confirmed by EPA, which
addresses step one.
Andover clearly identified design
parameters that are included in the
spreadsheets associated with the memo
under the tab ‘‘Plant Data Summary’’.
This includes plant data such as fuel,
capacity, capacity factor, heat rate,
baseline and controlled NOX level,
retrofit factor and firing configuration.
These parameters are directly used in
the cost analysis that developed capital
and annual costs. Andover performed
the cost estimates as described in the
spreadsheet. Andover considered site
and project-specific parameters as
described in other responses to
comments.
Commenters may disagree with the
cost methodology used by EPA, and our
response to comments regarding the cost
methodology used is in other responses;
however, there is no question that EPA
followed the three-step process.
Comment: The IPM methodology
relied upon in the Andover Report is
inconsistent with the three-step process
in the BART Guidelines for estimating
costs of compliance. The three-step
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process in the BART Guidelines
requires: (1) Identification of emission
units being controlled; (2) identification
of design parameters for emission
controls; and (3) development of cost
estimates based on those design
parameters. 70 FR 39166. The Andover
Report did not adequately define the
emission units being controlled, failed
to identify appropriate site-specific
design parameters that affect cost and
performance of these controls; and
developed cost estimates that are
neither technically indefensible nor
representative of the costs of SCR and
SNCR systems at Laramie River.
Andover’s reliance on the overly
simplistic IPM model precluded an
appropriate BART analysis. First,
because the IPM cost algorithms are
designed to provide high-level system
cost, Andover used generalized
information regarding design and
baseline operating conditions at the
Laramie River boilers to identify the
emission units to be controlled. Second,
because the IPM model includes only
four inputs, Andover’s cost analysis
could not account for unit-specific
operating parameters that affect both
design of the control system and the
attendant costs of installing the controls.
As a result, the Andover Report failed
to comply with the requirement in the
BART Guidelines that cost estimates
account for site-specific variables. 70 FR
39166. The site-specific design and
operational variables have an important
effect on the costs of NOX control
technologies at Laramie River,
particularly the installation of SCR.
Finally, because Andover used generic
inputs to an overly simplistic model, the
resulting cost estimate is not technically
defensible. As Sargent & Lundy opined
‘‘[b]ased on our evaluation of the
Andover cost estimates, it is our opinion
that cost estimates prepared by Andover
are not reflective of the costs BEPC
would incur to install air pollution
control systems on LRS Units 1, 2, & 3,
and that control technology costs
included in the February 7, 2013
Andover Report should not be used to
determine BART for the Laramie River
generating units.’’
Response: EPA disagrees with the
commenter. The three step process
requires that states (or EPA): (1) Identify
the emissions units being controlled; (2)
Identify design parameters for emission
controls; and (3) Develop cost estimates
based upon those design parameters.
Commenter states that ‘‘The Andover
Report did not adequately define the
emission units being controlled, failed
to identify appropriate site-specific
design parameters that affect cost and
performance of these controls; and
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developed cost estimates that are
neither technically indefensible nor
representative of the costs of SCR and
SNCR systems at LRS.’’ However, the
BART affected units were clearly
identified and defined in the analysis.
The units are identified and described
in the memo and the associated
spreadsheets.
EPA’s contractor clearly identified
design parameters that are included in
the spreadsheet associated with the
memo under the tab ‘‘Plant Data
Summary’’. This includes plant data
such as fuel, capacity, capacity factor,
heat rate, baseline and controlled NOX
level, retrofit factor and firing
configuration. These parameters are
directly used in the cost analysis that
developed capital and annual costs.
This is the very same data as used by
Sargent & Lundy in their analysis,
except that EPA did not correct for
elevation, which EPA is correcting in
this response to comments and
calculations.
Andover then performed the cost
estimates as described in the
spreadsheet using algorithms developed
by Sargent & Lundy that utilize the same
inputs as used by Sargent & Lundy in
their analysis for commenters. Other
than a site visit and an adjustment for
elevation, commenters have not
identified any other inputs that they
used that are different or not the direct
result of the inputs utilized by EPA.
With this response to comments EPA is
correcting cost estimates for elevation
and EPA has provided detailed
comments regarding how site
characteristics were addressed using
available satellite imagery and why this
is a valid approach for providing
estimates that are acceptable for BART
analysis.
We disagree with commenter’s
characterization of the cost development
methodology contained in IPM as
generalized. As noted in the
documentation for IPM’s cost
development methodology for SCR,174
the cost estimate methodology is based
upon two databases of actual SCR
projects. These databases include 2004
and 2006 industry cost estimates
prepared for the Midwestern Ozone
Group, and a proprietary in-house
database maintained by Sargent &
Lundy. The Midwestern Ozone Group
information was cross-referenced with
actual 2009 projects, and escalated
accordingly. Sargent & Lundy then used
the information in these databases to
develop the equations described in the
cost component taking into account the
174 https://www.epa.gov/airmarkets/progsregs/epaipm/docs/v410/Appendix52A.pdf.
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pre-control NOX emission level, degree
of reduction, coal type, facility size, and
numerous other unit-specific factors.
While a costly engineering evaluation
that included site visits in addition to
our use of satellite imagery would
potentially produce a more refined cost
estimate, we disagree that our approach
has produced cost estimates that do not
adequately address site-specific issues.
As noted by EPA in our responses
related to satellite imagery, EPA’s use of
satellite imagery enabled us to evaluate
each of the major site-specific issues
raised by commenters.
Comment: The Andover Report fails
to consider site-specific conditions as
required by the BART Guidelines. The
BART Guidelines and the CCM
emphasize the importance of taking into
account site-specific conditions in
developing a cost estimate, particularly
with respect to construction of SCR. 70
FR 39166 (cost estimates should ‘‘into
account any site-specific design or other
conditions . . .’’). See also CCM section
2.4, page 2–40 (with respect to SCR,
‘‘[a]ctual selection of the most costeffective option should be based on a
detailed engineering study and cost
quotations from system suppliers.’’); id.
section 2.5.4.1, page 2–27 (‘‘Manual
deviates from its standard approach of
providing study level costs [for SCR]
and, instead, provides a detailed
description of the factors’’ influencing
costs). Yet as Andover acknowledges in
its report, its engineers did not visit
Laramie River and had no engineering
plans, process flow diagrams, or other
site-specific information regarding
Laramie River when it developed EPA’s
cost estimate. The only information
Andover collected regarding the site
was the generating capacity of the
station, annual heat input for a baseline
period, NOX emission rates for certain
years, and the type of coal burned. As
a result, Andover’s cost estimation
methodology fails to comply with the
BART Guidelines or follow the
methodology recommended by the
CCM, and the final estimate radically
underestimates the cost for SCR and
SNCR at Laramie River Station.
Moreover, Andover’s use of the IPM
model compounded its failure to review
site-specific considerations relevant to
costing SCR or SNCR at Laramie River
Station. Indeed, the fact that the model
has only four input parameters, and
does not take into account other sitespecific parameters that are required by
the BART Guidelines and recommended
by the CCM, renders any resulting cost
estimate both technically and legally
deficient. As noted by Sargent & Lundy,
which developed the IPM algorithms for
SCR and SNCR, ‘‘[b]ecause of the
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limited number of site-specific inputs,
the IPM cost algorithms provide only
order-of-magnitude control system
costs, and do not provide case-by-case
project-specific cost estimates meeting
the requirements of the BART
Guidelines.’’
By relying on the IPM model,
Andover deliberately skirted the issue of
site-specific conditions, other than the
most generic inputs of unit size, heat
rate, coal type, and a retrofit factor. The
Andover Report describes the retrofit
factor in such a way as to emphasize its
site-specific nature, and yet makes no
attempt to carefully analyze the sitespecific variables inherent in the
application of the retrofit factor: ‘‘The
retrofit factor is a subjective factor used
to account for estimated difficulty of the
retrofit that is unique to the facility.
Because site visits were not possible, the
retrofit factor was estimated from
satellite images that provide some
insight to the configuration of the units
and degree of congestion around the site
and in the vicinity of where the SCR
would be installed. These factors impact
the ability to locate large cranes on the
site—that impact how the SCR is
assembled (are large sections lifted into
place or is the SCR ‘‘stick built’’), how
much duct work is needed, if the SCR
must be built onto a large, elevated steel
structure or can be built near the
ground, and if other equipment must be
relocated to accommodate the space of
the SCR.’’
The Andover Report never provides
any analysis of these site-specific factors
in determining the appropriate retrofit
factor for Laramie River. Andover
merely notes that the difficulties of
retrofitting an SCR unit at Units 1 and
3 is ‘‘average,’’ and applies a retrofit
factor of 1.0 to Units 1 and 3. Andover
does note that retrofit at Unit 2 will be
more difficult and added an adjustment
for retrofit difficulties at Unit 2, but
with no explanation of what unique
site-specific conditions contributed to
the factor. Instead, the report notes ‘‘a
modestly higher SCR retrofit difficulty
factor is assumed for Unit 2 because
access will be poorer than for Units 1 or
3.’’ In sum, Andover makes no
adjustments for Units 1 or 3 and accords
a 20% cost retrofit factor to Unit 2,
though it had previously noted that
‘‘when using the IPM Capital Cost
Model, retrofit difficulties associated
with an SCR may result in capital cost
increases of 30% to 50% over the base
model.’’ Thus, even when it accords a
retrofit factor, as it did for Unit 2,
Andover inexplicably low balls that
retrofit factor and the attendant cost
increase for the SCR system. When
Andover’s retrofit factors are compared
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across units and across facilities, it
appears that Andover arbitrarily
assigned the retrofit factors without
adequately accounting for site
congestion and constructability issues.
Subjective retrofit factors, especially
factors randomly chosen without
knowledge of site conditions, cannot
account for site-specific circumstances
as provided in the BART Guidelines.
A comparison of the broad brush
approach taken by Andover with the
detailed, site specific, scoping-level
study taken in the Sargent & Lundy
evaluation illustrates the inadequacies
with Andover’s methodology. As an
initial matter, Andover made a
fundamental error by failing to account
for the effect of site elevation on the
project costs. Laramie River Station is
situated at 4,750 feet above sea level,
resulting in flue gas volumes
approximately 20% greater than a
similarly sized unit at sea level. These
larger flue gas volumes will require
larger SCR reactors, larger duct work,
and increased structural support. None
of these additional costs are accounted
for in Andover’s estimate because the
IPM model assumes the plant is located
at sea level. Indeed, IPM model
guidance provides that ‘‘elevation of the
site must be considered separately and
factored into the MW size accordingly
due to its effects on the flue gas
volume.’’ Id. (citing the IPM SCR Cost
Development Document (August 2010)).
Andover’s reliance on the IPM model
also resulted in failure to account for a
regional labor productivity factor.
Regional productivity must be taken
into consideration in a site-specific cost
estimate to account for local workforce
characteristics, labor availability, project
location, project complexity, local
climate and working conditions. This is
a key factor for Laramie River Station,
because experienced, knowledgeable
labor is difficult to acquire and requires
premium pay, further adding to the cost
of an SCR system.
The most substantial failing of the
Andover Report, however, is its reliance
on an aerial photograph of the plant
from Google EarthTM to account for sitespecific conditions at Laramie River
Station. There are numerous important
elements that cannot be discerned from
an aerial photograph. Specifically, a
Google EarthTM photograph cannot
identify: (1) The site constraints posed
by the location of the coal conveyor
rooms; (2) the location of the existing
fan buildings and the space constraints
between the existing fan buildings and
the existing electrostatic precipitators;
(3) the necessary information to
determine duct work routing and SCR
tie-ins to the existing economizers and
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air heaters; and (4) information
regarding plant subsystems such as the
fan capacity, equipment reinforcement,
auxiliary power systems, electrical plant
system capacity, and other plant
subsystems that would be affected by
installation and operation of the SCR
systems. Further, the aerial photograph
provides no information about where
the ammonia handling system could be
located and necessary pipe routing and
other support systems for the ammonia
handling system. Nor does it show the
need to penetrate the 20-story boiler
wall and provide related structural
support to install duct work, to provide
structural support columns for the SCR
reactors in very tight spaces, and the
need for special cranes to lift heavy
equipment into place in a congested
space.
While Andover indicated that some of
these site-specific issues are addressed
by the retrofit factor, the fact that
Andover accorded no retrofit factor to
Laramie River Station Units 1 and 3,
and low balled the retrofit factor for
Unit 2, resulted in a failure to include
site-specific costs in its estimate for the
Laramie River, in direct contravention
of the requirements of the BART
Guidelines and suggestions of the CCM.
Site-specific conditions are illustrated
in Section 5.1.1.1 of the Sargent &
Lundy Critique. Finally, Andover failed
to include costs for the balance of plant
systems required for the SCR. Sargent &
Lundy Critique section 5.1.1.3. These
items, which require enlarging existing
plant systems to provide for the
additional power and airflow and other
systems necessary to operate the SCRs,
include the following: (1) Replacement
of induced draft fans by larger fans to
support the SCR units; (2) Upgrading of
the existing electrical system to support
the SCR units; (3) Structural stiffening
of the duct work downstream of the
SCRs; and (4) Expand existing control
system to accommodate six new SCRs
(two for each generating unit).
Wyoming used actual, site-specific
data regarding the BART-eligible
sources in development of its plan. In
contrast, EPA did not use site-specific
data; instead, it relied on nothing more
than aerial photographs available in the
public domain.
Response: EPA disagrees with the
commenter. First, as discussed
elsewhere in responses, we are no
longer relying on the IPM cost
algorithms, including the application of
retrofit factors, to estimate capital costs
for the Laramie River Station units.
Instead, we have evaluated the cost
information provided by Basin Electric
in comments and incorporated it as
appropriate. Therefore, the arguments
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made by the commenter related to our
use of the IPM algorithm are no longer
relevant. Nonetheless, below we discuss
how our use of the IPM algorithm in the
proposed rule was based on reason and
evidence and addressed the site-specific
concerns raised by the commenter.
As noted in responses to other
comments, EPA adequately addressed
site-specific issues in using the IPM SCR
cost model. The SCR cost model for
IPM, being developed from actual SCR
retrofit data, incorporate all of the costs
that would normally be associated with
an SCR retrofit. As such, retrofit issues
that are common to all SCR retrofits are
incorporated into the cost. To the extent
that there are additional costs, as
described in other comments, these can
be addressed with the retrofit difficulty
factor.
Basin Electric did not follow the
BART guidelines in developing their
cost analyses, and importantly, did not
provide adequate documentation when
they deviated from it. There are only
very limited situations under which an
analyst can depart from the CCM
methodology under the BART
Guidelines: ‘‘The basis for equipment
cost estimates also should be
documented, either with data supplied
by an equipment vendor (i.e., budget
estimates or bids) or by a referenced
source (such as the OAQPS CCM, Fifth
Edition, February 1996, EPA 453/B–96–
001). In order to maintain and improve
consistency, cost estimates should be
based on the OAQPS CCM, where
possible. The CCM addresses most
control technologies in sufficient detail
for a BART analysis. The cost analysis
should also take into account any sitespecific design or other conditions
identified above that affect the cost.’’ 70
FR 39166.
This section of the BART Guidelines
makes it clear that the CCM is the
intended methodology for conducting a
BART cost determination. It also states
why: To maintain and improve
consistency. However, the CCM does
state that site-specific conditions should
be incorporated. Site-specific conditions
could include space constraints, or a
design feature that could complicate
installing a control. Importantly, a
footnote at the bottom of the same page
of the BART Guidelines makes it clear
that the analyses should document any
deviations from the CCM: ‘‘You should
include documentation for any
additional information you used for the
cost calculations, including any
information supplied by vendors that
affects your assumptions regarding
purchased equipment costs, equipment
life, replacement of major components,
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5147
and any other element of the calculation
that differs from the CCM.’’
The record does not point to any
‘‘unusual circumstance’’ that explains
why Basin Electric’s SCR costs are
higher than costs of SCRs at other
similar facilities, other than the use of
a different cost methodology. In fact,
there is nothing in the record to support
claims that the cost of SCR was in fact
based on detailed site-specific vendor
bids, or is in any manner more sitespecific than the costs relied upon by
EPA in our proposed rule. As an
example, the BART application
submitted by Basin Electric, and relied
upon by Wyoming, shows that only the
cost of catalyst is based on a vendor
quote.175 There is no documentation to
substantiate that the remaining costs are
based on vendor quotes or any other
site-specific data. The mere fact that the
cost analysis was submitted by Basin
Electric is not a basis to conclude that
it is somehow highly site-specific.
Indeed, even the updated cost
information recently submitted by Basin
Electric during the comment period is
conceptual in nature and not based on
vendor quotes. As stated on page 21 of
Exhibit 14 to their comments: ‘‘The LRS
cost estimates are conceptual in nature;
thus, S&L did not procure equipment
quotes specifically for the LRS control
systems. Rather, equipment costs for the
LRS projects are based on conceptual
designs developed for the control
systems, preliminary equipment sizing
developed for the major pieces of
equipment, and recent pricing for
similar equipment.’’
Commenter correctly notes that EPA
did not account for elevation. EPA
acknowledges that it did not account for
elevation in the estimate when using the
IPM algorithm and EPA’s revised
estimate does account for elevation.
Commenter states that the regional labor
productivity was not factored into EPA’s
estimate. EPA’s estimate did provide an
allowance for overtime which is a line
item in the estimate labeled ‘‘Labor
Adjustment.’’ However, commenter did
not provide sufficient information to
evaluate commenter’s estimate and how
productivity factors were developed or
applied in their estimate to produce
their estimate. Labor costs comprise
roughly half of the total cost of Basin
Electric’s estimate of what SCR would
cost to install at Laramie River Station,
and the significance of this cost makes
the lack of information very important.
175 Wyoming Regional Haze SIP, Attachment A,
‘‘Basin Electric Power Cooperative Laramie River
Station Refined BART Visibility Modeling’’,
prepared for Basin Electric Power Cooperative by
Black & Veatch Corporation, July 24, 2008,
Attachment 1, page 7 of 7.
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Moreover, if this is an important
element of commenter’s critique of
EPA’s method, they should have
provided sufficient data and supporting
justifications for EPA to evaluate
commenter’s estimate. Notably, this is
an important deviation from the CCM
and more detailed supporting data
should have been provided. As noted in
EPA’s responses to other comments, the
commenter has not provided any data to
explain the high labor charge rates or
claimed low productivity, as required
under the BART Guidelines.
Commenter claims that ‘‘a Google
EarthTM photograph cannot identify: (1)
The site constraints posed by the
location of the coal conveyor rooms’’.
On the contrary, the coal conveyors are
prominent features in the images 176 and
it is clear from the coal conveyors where
the coal conveyor rooms are located.
This location for coal conveyor rooms is
not unusual. In general, coal conveyor
rooms are located either to one side of
the boiler or the other, depending upon
the location of the coal pile to the boiler.
Moreover, the resulting need to route
ductwork through the boiler building
wall is commonly performed in SCR
retrofits. As such, this is not an unusual
issue and should not significantly
impact retrofit cost versus a typical
retrofit.
Commenter claims that EPA did not
account for ‘‘(2) the location of the
existing FD fan buildings and the space
constraints between the existing FD fan
buildings and the existing electrostatic
precipitators . . .’’ It is clear from the
images that there is a building located
immediately below where the SCR
reactor would be located, and this is not
an unusual situation. The location of the
ESP is also very clearly shown on the
images. The space between the ESP and
the fan rooms is also visible from the
photo in Figure 6a of the Andover
memo. Nevertheless, having to install
SCR support structure in close
proximity to existing buildings or
equipment, as may be necessary at
Laramie River, is not unusual because
SCRs are commonly erected in that
location and buildings or other
equipment are normally in the area
below. It is also possible that SCR
support structure could be built to
largely avoid the forced draft fan
buildings by extending beyond them
with a common support structure for all
three, or at least more than one, SCR
reactor. The space between the ESP and
the fan buildings is only significant with
176 Review of Estimated Compliance Costs for
Wyoming Electric Generating (EGUs)—Revision of
Previous Memo, memo from Jim Staudt, Andover
Technology Partners, to Doug Grano, EC/R, Inc.,
February 7, 2013, Figures 6a and 6b.
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regard to location of a crane for erection
of Unit 2, and this is why a higher
retrofit difficulty is assumed for Unit 2.
Middle unit crane access issues are not
unusual either and have been addressed
numerous ways, including assembling a
temporary crane above the boiler
building, as was performed at the
Brayton Point plant for their Unit 3.
Commenter claims that EPA did not
adequately account for ‘‘(3) the
necessary information to determine duct
work routing and SCR tie-ins to the
existing economizers and air heaters
. . .’’ EPA disagrees with the
commenter. The general routing can be
estimated from the images, and there
was nothing in the images to suggest
any problems with routing ductwork. It
was apparent that a penetration was
necessary in the boiler building, which
is routinely necessary because boilers
are typically housed in boiler buildings
and the SCRs are not, making
penetration of a boiler building wall
necessary in any SCR retrofits where the
boiler is in a boiler building. This is the
case with most SCR retrofits. In fact,
Figures 2 and 3 of Exhibit 16 to Basin
Electric’s comments demonstrate that
the ductwork tie in to the boiler and
associated modifications are similar to
what is done routinely and ductwork
length is reasonable. For an SCR cost
estimate, the most critical cost issues
that require closer examination than
possible with a satellite photo is if it is
necessary to move major pieces of
equipment, such as an air preheater, in
order to accommodate the ductwork.
Had it been determined that relocating
the air preheater was necessary, this
would entail some significant additional
cost over what would be considered a
‘‘typical’’ retrofit. Basin Electric did not
indicate any such need and therefore
their costs for ductwork are expected to
be within the normal cost for a retrofit.
Commenter claims that EPA did not
properly account for ‘‘(4) information
regarding plant subsystems such as the
FD fan capacity, equipment
reinforcement, auxiliary power systems,
electrical plant system capacity, and
other plant subsystems that would be
affected by installation and operation of
the SCR systems. Sargent & Lundy
Critique section 5.1.1.2.–5.1.1.3.’’ The
IPM algorithm explicitly assumes that it
will be necessary to replace the forced
draft (FD) fan 177 and make
modifications to auxiliary electrical
systems and associated boiler structure
177 Sargent & Lundy, ‘‘IPM Model—Revisions to
Cost and Performance for APC Technologies—SCR
Cost Development Methodology, FINAL’’, August
2010.
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and has a line item cost for this. As such
this was addressed in the cost.
Commenter claims that ‘‘Further, the
aerial photograph provides no
information about where the ammonia
handling system could be located, and
necessary pipe routing and other
support systems for the ammonia
handling system. Nor does it show the
need to penetrate the 20-story boiler
wall and provide related structural
support to install duct work, to provide
structural support columns for the SCR
reactors in very tight spaces, and the
need for special cranes to lift heavy
equipment into place in a congested
space.’’ EPA disagrees. It is apparent
from the image, and the open spaces on
the images that have no structures, that
there are any of a number of places at
the Laramie River site that the ammonia
storage system could be located.
Selecting the ideal location does require
closer examination of the site than
possible with an aerial photograph.
However, the impact on total capital
cost is relatively small. With regard to
modifications to the boiler building, this
has already been discussed along with
the installation of structural support
columns for the SCR and need for
cranes. These modifications are
routinely necessary for SCR retrofits and
would be factored into the historical
SCR projects that the IPM algorithms are
based upon.
Expansion of the controls is another
cost identified by commenters as not
adequately addressed by EPA. EPA
disagrees with commenter. Every SCR
retrofit requires expansion of controls.
So, this is incorporated into the IPM
model. There may be specific issues that
may be associated with tailoring the
controls to the existing site that make
this portion of the cost slightly more or
slightly less expensive than normal. But,
controls are generally a small
contributor to total SCR cost and these
differences would have a minor effect.
Comment: When all of the sitespecific and balance of plant conditions
are included, Sargent & Lundy
estimated that the capital cost of
installing SCR at Laramie River Station
is $746,906,000. This is twice as much
as Andover’s flawed cost estimate of
$330,000,000. The discrepancy in the
cost estimates is not surprising in light
of Andover’s failure to comply with the
BART Guidelines and to follow the
CCM where appropriate. For example,
the site congestion and balance-of-plant
upgrades alone total approximately
$290 million—costs which accurately
reflect site-specific constraints to
installing SCR, but which were not
accounted for in the Andover Report.
While the costs estimated in the Sargent
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& Lundy Evaluation are significantly
greater than those set forth in the
Andover Report, they are a far more
accurate and representative assessment
of the costs of installing SCR and SNCR
at Laramie River Station.
Response: EPA disagrees with the
commenter, having found the following
discrepancies in the commenter’s
estimates for cost of SCR and SNCR at
Laramie River Station:
1. Apparently Double-Counts General
Facilities
The itemized cost estimate in the
Appendices to Exhibit 14 includes items
that are normally incorporated into the
General Facilities cost, while Sargent &
Lundy took an additional provision for
General Facilities (Exhibit 14 at page
31). General Facilities are costs that are
not directly associated with the process
equipment, and include such things as
access roads, access platforms, safety
equipment (such as eye-wash stations),
etc. On the other hand, ductwork,
piping, structural steel to support
process equipment are direct capital
cost and do not fall into the category of
General Facilities. The itemized cost
estimate by Sargent & Lundy in the
Appendices to Exhibit 14, however,
includes the cost of many items that
would normally fall under the category
of General Facilities. This includes the
cost of roads and a parking area
($930,226 at page 2 of SCR estimate),
eye wash stations (page 3), a preengineered building for the construction
warehouse ($780,000 page 8), fire
protection systems (page 16), gratings,
handrails, ladders (page 22). As a result,
Sargent & Lundy double counts for
General Facilities by having these costs
accounted for in the itemized direct
capital cost as well as in its Indirect
Capital costs.
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2. Labor Rates in Sargent & Lundy’s
Itemized Capital Cost in the Appendices
to Exhibit 14 Appear To Already Have
a Significant Contingency Built in and
Additional Costs for Overtime and Per
Diem—Already Incorporating
Contingency in Apparent DoubleCounting of Contingency
According to Basin Electric’s
comments, their labor rates were taken
from the publication RS Means.178
However, examples of how the labor
rates from RS Means were used to
develop what was ultimately used in
their estimate were not provided. RS
Means is a subscription service that can
cost up to $1,100, depending upon the
package.
178 Exhibit
14, page 25.
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However, there are publicly available
labor rates for the major construction
trades from the CLRC that are available
for download at the National
Association of Construction Boilermaker
Employers’ Web site.179 The Laramie
River Station estimate assumes
boilermaker labor tasks with a labor rate
of $90.79/hr while according to the
CLRC boilermaker rates in the Mountain
and Northwest Plains as of July 2013
were $56.79/hour, which is close to the
values for Lodge 101 of the boilermakers
union, ranging from $57.62 for a
Journeyman to $60.12 for a Foreman,
and lower rates for apprentices.
The Laramie River estimate assumes
pipefitter labor tasks with a labor rate of
$81.72/hour, while according to the
CLRC pipefitter rates in the Mountain
and Northwest Plains as of July 2013
were $43.57/hour. Plumber rates are
only slightly higher are $47.47/hour. In
fact, there are several areas where the
Laramie River itemized estimated rates
in the Appendices far exceed MountainNorthern Plains reported rates for union
craft labor for July 2013. The ratio of
assumed rate versus reported is as high
as 187%. It is only for the installation
of an architectural door that the
reported rate for carpenters is even close
to the assumed rate for Laramie River
Station. Carpenters also build concrete
forms.180 For carpenters doing concrete
forms, the paid rate ($65.02—see page 2
of estimate) is more than double the
union rate. For most of these crafts,
these rates cannot be explained by per
diem. For example, if all of the
boilermakers lived 120 miles from the
location and were eligible for $70/day
per diem and also drove 120 miles each
way every day of an eight-hour shift
receiving $0.565/mile, that would only
increase the hourly rate by $25.70,
which does not explain the $34+
difference.
It may be that Sargent & Lundy
applied an escalation to the labor
charges for future expected rates. If so,
this is inconsistent with the CCM,
which does not allow for this. In light
of the fact that labor comprises the
single largest expense and is nearly half
of the total direct cost of the project—
per Basin Electric’s estimate in the
Appendices to Exhibit 14—the high
labor rates assumed by Sargent & Lundy
are critical cost items that require much
more complete explanation than was
provided.
179 Construction Labor Research Council Union
Wages and Supplements, available from the
National Construction Boilermaker Employers Web
site, www.nacbe.com.
180 Bureau of Labor Statistics, 47–2031
Carpenters, www.bls.gov/oes/current/
oes472031.htm.
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3. Additional Labor Costs
In addition to the high labor rates
incorporated into Sargent & Lundy’s
itemized estimate, roughly $47 million
in additional labor costs are included
for five ten-hour days and six ten-hour
days and per diem.181 This schedule
(which results in overtime) is stated to
be necessary to attract necessary
labor.182 No further explanation is
provided for these costs. It is unclear
why it is necessary to offer these in light
of the fact that power plant construction
labor demand is well off of its peak and
is especially low in the Western States.
As a key power plant construction trade,
boilermaker man-hours are a good
indication of general power plant
construction activity. Boilermaker manhours demonstrate that labor demand is
well off of past peaks, and for the first
two quarters of 2013, boilermaker
employment in the Western States is
18.6% below 2012 levels for the same
period. Boilermaker man-hours in 2012
nationally totaled 27 million, well off
the years of 2006 through 2009 that
were all above 30 million, and peaked
in 2008 at over 40 million. 2012 levels
were still below 2010’s rate of 28
million.183
It is also unclear why such high
expenses are needed for overtime and
per diem, particularly in light of the
high assumed wage rates discussed
earlier. Moreover, the need for overtime
needs to be incorporated into a
discussion of schedule, which was not
provided. The time available for
installing the SCRs may allow for
spreading of activities over longer
periods of time than in past retrofit
efforts that may have allowed less time
than the RHR, which allows for five
years. However, there is no discussion
of the need for overtime in the context
of schedule.
4. Quantity and Cost of Materials and
Impact on Labor Hours
Throughout the spreadsheets
provided as Attachments to Exhibit 14
to Basin Electric’s comments, no
information was provided on how the
quantities of materials were estimated,
such as tons of steel for ductwork, etc.
This makes it impossible to evaluate if
Sargent & Lundy estimated the correct
quantities of materials, associated
material costs, or the associated hours
181 Appendices to Exhibit 14 of Basin Electric
comments, page 4 of SCR estimate.
182 Exhibit 14, page 25.
183 https://nacbe.com/manhour-reports/. Also see:
Staudt, J.E., ‘‘Engineering and Economic Factors
Affecting the Installation of Control Technologies—
An update’’, Developed for U.S. EPA Clean Air
Markets Division, December 15, 2011, figure 2–2 on
page 12.
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associated with erecting the materials.
The spreadsheet was provided as a pdf
document, and therefore any underlying
equations could not be examined. As
noted in our comments to other
questions, it is necessary to include
documentation for any additional
information used for the cost
calculations that differs from the CCM.
Since the quantities of materials also
relate to the labor needed to install the
materials, this also impacts the labor
costs estimated by Sargent & Lundy.
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5. AFUDC
Sargent and Lundy includes AFUDC
in its SCR cost. This cost of about $22–
$23 million cost per unit, for a total of
$68 million, is not permissible under
the CCM as discussed in response to
other comments.
6. Process Contingency
Although the CCM shows an
allowable process contingency of 5% for
SCR, in EPA’s opinion, this is not
necessary today for SCR on coal-fired
boilers firing the coals used in
Wyoming. According to the Department
of Energy’s NETL: 184 ‘‘Process
contingency is intended to compensate
for uncertainty in cost estimates caused
by performance uncertainties associated
with the development status of a
technology. Process contingencies are
applied to each plant section based on
its current technology status.’’
According to this document, for
commercially available technologies
process contingency could range from
0–10%. When the CCM was issued in
January 2002, SCR was commercially
available but was only emerging in
application on coal-fired utility boilers
in the U.S. According to a study by
Cichanowicz,185 at the end of 2001,
there was only about 13,000 MW of coal
SCR capacity in the U.S., with nearly all
installed in the prior two years, meaning
that there was very limited long-term
experience with SCR on U.S. coals. SCR
usage on coal-fired boilers has since
increased about ten times to about
130,000 MW of coal capacity (over 40%
of all coal capacity) and is therefore a
very well proven and well understood
technology on a wide range of U.S.
coals. As a result, the process
contingency for SCR on coal-fired utility
boilers should be much lower today
than what it was when the CCM was
184 U.S. Department of Energy, National Energy
Technology Laboratory, ‘‘Cost Estimating
Methodology for NETL Assessments of Power Plant
Performance’’, DOE/NETL–2011/1455, April 2011,
pg 4.
185 From data in Cichanowicz, J., Muzio, L., Hein,
M., ‘‘The First 100 GW of SCR in the U.S.,—What
Have We Learned?’’—2006 Mega Symposium.
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issued in January 2002—5%. EPA
believes that for SCR applications on
utility boilers burning Powder River
Basin coals, which are very well
understood SCR applications, there
should not be a need for process
contingency.
7. Sulfur Trioxide (SO3) Mitigation
Measures Are Not Needed
Sargent & Lundy assumed that a SO3
mitigation system is necessary for the
Laramie River SCR. We disagree as this
adds unnecessary capital and operating
cost. An SO3 mitigation system is
unnecessary because of the relatively
low sulfur content of the coal and the
fact that the coal fly ash is high in free
calcium oxide. The available free lime
will neutralize the SO3 making SO3
mitigation unnecessary. In fact, in the
model they developed for the IPM,
Sargent & Lundy assumed that SO3
mitigation was unnecessary for boilers
using coals with SO2 levels below 3 lb/
MMBtu, making it unnecessary for
Laramie River, which fires a much
lower sulfur coal from the Dry Fork
Mine, with an uncontrolled SO2 rate of
roughly 0.50 to 1.0 lb/MMBtu.186 187 188
In fact, Sargent & Lundy uses the same
rationale for arguing (correctly) that air
preheater modifications are not
necessary to address potential
ammonium bisulfate formation from an
SNCR system.189 Moreover, even if SO3
formation were a legitimate concern,
low oxidation SCR catalysts are
available and any additional cost impact
would be very small. SO3 mitigation is
not a large capital cost compared to the
other costs that contribute to the SCR,
but it is illustrative of the manner in
which Sargent & Lundy has taken efforts
to overdesign the system while adding
unnecessary costs.
8. Labor Productivity Factor Apparently
Not Site-Specific
Basin Electric has commented that
local labor productivity is a major factor
that impacts cost. However, it appears
that the labor productivity factor being
selected at the site may have been
broadly applied by Sargent & Lundy at
multiple sites in an inconsistent
manner. According to Basin Electric,
‘‘Labor productivity accounts for things
186 Sargent & Lundy, ‘‘IPM Model—Revisions to
Cost and Performance for APC Technologies—SCR
Cost Development Methodology, FINAL’’, August
2010, page 5.
187 https://www.westernfuels.org/member-services/
mining-operations
188 BNSF Mine Guide, at www.bnsf.com/
customers/pdf/mineguide.pdf. SO2 calculated by
multiplying sulfur content (expressed as a decimal)
times 2 million and dividing by the heating value
in Btu/lb.
189 Exhibit 14, page 17.
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such as labor availability, site access
and working conditions, climate, season
changes, and project size and
complexity’’ and it is a common
practice on large construction projects
to apply a productivity factor to account
for local worker productivity and
construction site conditions. A labor
productivity factor of 1.15 was selected
to account for labor productivity in the
southeastern Wyoming region as
compared to the benchmark of 1.00 for
Texas, cited in Basin Electric’s
comments. Although the comments
refer to the Compass International
Global Construction Cost and Reference
Yearbook, the value in that document
for the southeastern Wyoming region is
not expressly stated, and it is unclear if
1.15 is, in fact, the value in that
document as we were not able to
confirm the number in the document
referenced.190
In another Sargent & Lundy BART
analysis, performed for Oklahoma Gas &
Electric Sooner Units 1 & 2 and
Muskogee Units 4 & 5, Sargent & Lundy
also used a Labor Productivity factor of
1.15.191 Since the Oklahoma Gas &
Electric units are in a climate far more
similar to Texas (only about 150 miles
from Texas) than Wyoming, and the
Oklahoma plant likely draws from
similar construction labor pools as
Texas, it seems that they should have a
similar productivity factor as Texas. It is
also unusual that Sargent & Lundy
would select the exact same
productivity factor for the Oklahoma
BART analysis as Laramie River
Station’s BART analysis, although these
facilities are roughly six hundred to
seven hundred miles away, with very
different climates and draw on different
labor pools. In this case, it appears that
Sargent & Lundy has used the same
productivity factor for Laramie River
Station as for other BART analyses. In
summary, there is no evidence that the
labor productivity factors suggested by
the commenter are site-specific.
9. Contractor’s Fees and Profit Are
Excessive
Commenter’s estimate for contractor’s
fees Expense and Profit total nearly $51
million, or 14% of the estimated total
Labor, Material, Subcontract, and
Process Equipment.192 By contrast,
Sargent & Lundy estimated for the IPM
algorithm total contractor fees and
profits of 10% of the estimated Labor,
190 Exhibit
14, page 25.
Gas & Electric, ‘‘Sooner Units 1 &
2, Muskogee Units 4 & 5 Dry FGD BART Analysis
Follow-Up Report’’, December 28, 2009, see pdf
pages 28 and 43.
192 Attachments to Exhibit 14 to Basin Electric
Comments, page 4 of SCR estimate.
191 Oklahoma
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Material, Subcontract, and Process
Equipment cost. When this higher
percentage is combined with a high
direct cost, the contractor’s fees become
excessive. The high contractor fees and
profits assumed in the Laramie River
Station estimate also seem inconsistent
with a weak power plant construction
market, as demonstrated by the
boilermaker man-hour data discussed
earlier.
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10. Labor, Material, Subcontract, and
Process Equipment Costs in Excess of
Historical Norms, With Substantial
Additional and Unnecessary Costs
Added
It is not unusual for owners to report
excessive costs because owners are most
interested in a cost estimate that has a
very low risk of an overrun rather than
a ±30% cost estimate, which has a
higher risk of overrun (about 50%), but
is likely to be a better estimate of actual
project cost. Commenter’s estimate for
total Labor, Material, Subcontract, and
Process Equipment is $361 million.
Adding Sargent & Lundy’s estimated
cost of scaffolding, freight, and
consumables that is in the Appendices
to Basin Electric’s Exhibit 14 to their
estimated Labor and Material,
Subcontract, and Process Equipment
raises the cost to $383 million (Sargent
& Lundy provides no supporting
documentation for this $22 million in
additional cost). This is 27% above the
expected cost of $301 million (with
elevation accounted for) developed from
the IPM SCR model, which is developed
from actual project data. This suggests
that Sargent & Lundy made a fairly
conservative estimate of these costs for
Basin Electric. But, in addition to the
cost of Labor, Material, Subcontract, and
Process Equipment, scaffolding,
consumables and freight, in their
estimate for Basin Electric, Sargent &
Lundy added very high costs for
overtime, per diem (that were not
explained as required) and high costs
for contractor’s fees and profits, and
then added additional project and
process contingencies, unnecessary
costs such as SO3 mitigation and unallowed costs such as AFUDC that
increased total project cost to nearly
$750 million—about double what they
had estimated in 2008.193 The combined
effect of the conservative cost estimates
with additional contingencies or
unnecessary cost adders, results in what
appears to be an unrealistically high
cost.
193 Attachments to Exhibit 14 to Basin Electric
Comments, page 4 of SCR estimate and Exhibit 14
page 31.
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11. Project Contingency of 15% Is Too
High in Light of the Method Used and
Very Conservative Underlying
Assumptions
Because the cost estimates developed
for Basin Electric are already very
conservative, and based upon detailed
estimates of the labor and materials to
build the SCR, a 15% project
contingency is excessive. According to
the CCM, Section 1.1 Chapter 1, page 1–
4: ‘‘The accuracy of the information in
the Manual works at two distinct levels.
From a regulatory standpoint, the
Manual estimating procedure rests on
the notion of the ‘‘study’’ (or rough
order of magnitude—ROM) estimate,
nominally accurate to within ± 30%.
This type of estimate is well suited to
estimating control system costs
intended for use in regulatory
development because they do not
require detailed site-specific
information necessary for industry level
analyses.’’
The methods and cost elements of the
CCM were adapted from the American
Association of Cost Engineers (AACE)
(CCM Section 1, Chapter 2, p 2–5).
AACE 16R–90 194 states that, ‘‘Project
Contingency is included to cover the
costs that would result if a detailed-type
costing was followed as in a definitivetype study.’’ According to NETL,195
‘‘AACE 16R–90 states that project
contingency for a ‘‘budget-type’’
estimate (AACE Class 4 or 5) should be
15% to 30% of the sum of BEC, EPC fees
and process contingency.’’ AACE 18R–
97 196 defines different classes of
estimates, from 5 (least detailed) to 1
(most detailed). The methodology used
in the CCM falls into a Class 4 or Class
5, while the methodology used by Basin
Electric in their comments, with
hundreds of line items and thousands of
input parameters, is clearly a far more
detailed estimate that does not leave out
any aspect of the project.
The 15% project contingency factor in
the CCM for SCR shown in Table 2.5 on
page 2–44 of Section 4.2 Chapter 2 is
based upon use of the cost estimating
method described in the CCM to
develop the Total Direct Capital Costs.
It is not intended to apply to a detailed
estimate that: (1) Includes many cost
items not explicitly included in the
estimating method described in the
CCM to develop the Total Direct Capital
194 AACE Recommended Practice, AACE 16R–90;
www.aacei.org/non/rps/18R-90.pdf.
195 U.S. Department of Energy, National Energy
Technology Laboratory, ‘‘Cost Estimating
Methodology for NETL Assessments of Power Plant
Performance’’, DOE/NETL–2011/1455, April 2011,
pg 5.
196 AACE Recommended Practice, AACE 16R–87;
www.aacei.org/non/rps/18R-97.pdf.
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Costs and meant to be included in the
15% project contingency, and (2)
Already has substantial contingency
built into it through conservative
assumptions.
In fact, the CCM discusses the
importance of not double-counting
contingency in multiple places such as
retrofit factor and contingency at page
2–30 of Chapter 2—Cost Estimation:
Concepts and Methodology: ‘‘Due to the
uncertain nature of many estimates,
analysts may want to add an additional
contingency (i.e., uncertainty) factor to
their estimate. However, the retrofit
factor is a kind of contingency factor
and the cost analyst must be careful to
not impose a double penalty on the
system for the same unforeseen
conditions. Retrofit factors should be
reserved for those items directly related
to the demolition, fabrication, and
installation of the control system. A
contingency factor should be reserved
(and applied to) only those items that
could incur a reasonable but
unanticipated increase but are not
directly related to the demolition,
fabrication, and installation of the
system. For example, a hundred year
flood may postpone delivery of
materials, but their arrival at the job site
is not a problem unique to a retrofit
situation.’’ (emphasis added). The CCM,
therefore, explicitly anticipates that
some analysts may, incorrectly, apply
multiple contingencies for the same
areas of uncertainty even when using
the methods described in the CCM for
estimating Total Direct Capital Costs.
Because the cost estimates developed
for Basin Electric are already very
conservative and based upon detailed
estimates of the labor and materials to
build the SCR, rather than study-level
estimates, they have double-counted
both the costs that are intended by the
CCM to be included in the project
contingency when using the CCM
method, plus they have added
additional contingency in the form of
conservative assumptions to address
uncertainties in their estimate. For this
reason a 15% project contingency is
excessive for their estimate.
12. The Cost Information in Exhibit 14
Does Not Appear To Be Consistent With
the Cost Information in the Appendices
to Exhibit 14
The table on page 4 of the SCR cost
estimate for Units 1–3 shows a total cost
of $481 million. This is inconsistent
with the Total Direct Capital Costs
shown on page 31 of Exhibit 14, which
total $465 million. It is unclear what the
cause of the $16 million difference is. In
either case, EPA believes that the cost is
not adequately explained.
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13. Laramie River Station Does Not
Require an SNCR System With Four
Injection Zones
The Laramie River Station is a base
loaded unit, with capacity factors well
above 80%. This means that the boiler
rarely operates at part load. Sargent &
Lundy designed the SNCR system with
four injection zones to accommodate the
‘‘entire load and temperature range
within the boiler’’.197 Because the unit
will rarely operate at part load and the
emission rate is a 30-day average, there
is likely no need for four injection
levels. Four injection levels are only
required on load-following units that
spend a significant amount of time at
low or middle loads or units that must
comply with emission limits of much
shorter averaging times, such as 24 hour
averages or less. In practice, this system
would be designed with two, or, at
most, three injection zones. The
additional injection zone adds cost in
the form of additional injectors and
furnace penetrations, and associated
labor. On the other hand, EPA has
accepted Basin Electric’s estimate of the
cost of the SNCR system. Although we
believe that there would likely be fewer
injection levels, based upon the furnace
exit temperature reported by the
company, we expect that at least one of
the injection levels will require a
convective zone injection system using
multi-nozzle lances, which will increase
the cost. Therefore, these effects offset
one another and we are accepting the
cost provided by Basin Electric.
14. Similar Labor Rate Issues for SNCR
as for SCR Estimate
Examination of the labor rates for the
Sargent & Lundy cost estimate revealed
that Sargent & Lundy assumed the same
high labor rates for crafts as they did for
SCR without the rates explained
sufficiently. They also assumed an
additional $2.7 million in additional
overtime and per diem rates that are not
explained.198
For these reasons, the Sargent &
Lundy capital cost estimates for SCR
and SNCR are deficient, for the reasons
as described above. However, because
EPA expects that the SNCR injection
system necessary for Laramie River
Station may require more costly
multiple-nozzle lances in at least one
injection zone, this should offset the
cost impact of the deficiencies we have
identified, and we are accepting the
capital cost of the SNCR system
provided by Basin Electric equal to
$16.9 million per unit.
197 Exhibit
14, page 17.
to Exhibit 14 of Basin Electric
comments, page 4 of SNCR estimate.
198 Appendices
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For the SCR capital cost at Laramie
River, EPA is accepting some costs and
not others, as described in more detail
in supporting information with these
comments.199
Comment: We are very concerned to
see that EPA has introduced a retrofit
factor greater than ‘‘1’’ (the default) for
13 of the 15 EGUs evaluated. The IPM
model used by EPA to estimate control
costs in Wyoming already includes
retrofit costs in its costing algorithms. It
is generally accepted that retrofit
projects will incur costs over and above
those for a ‘‘greenfield’’ site, and most
of those retrofit costs are already
included in the database used to
generate the IPM algorithms. So, unless
a particular situation is so extreme as to
warrant an additional retrofit factor,
applying a retrofit factor to an algorithm
that already includes retrofit costs is
double counting those costs. Not only is
the application of a retrofit factor not
mentioned in the Federal Register
Notice, its only supporting
documentation appears in docket item
EPA–R08–OAR–2012–0026–0086[1],
‘‘Review of Estimated Compliance Costs
for Wyoming Electricity Generating
Units (EGUs)—revision of previous
memo’’: ‘‘Selective Catalytic NOX
Reduction (SCR) capital cost is
estimated using the IPM algorithms with
retrofit factors adjusted on a unit by unit
basis.’’ The retrofit factor is a subjective
factor used to account for the estimated
difficulty of the retrofit that is unique to
the facility. Because site visits were not
possible, the retrofit factor was
estimated from satellite images that
provide some insight to the
configuration of the units and degree of
congestion around the site and in the
vicinity of where the SCR would be
installed. These factors impact the
ability to locate large cranes on the
site—that impact how the SCR is
assembled (are large sections lifted into
place or is the SCR ‘‘stick built’’), how
much ductwork is needed, if the SCR
must be built onto a large, elevated steel
structure or can be built near the
ground, and if other equipment must be
relocated to accommodate the space of
the SCR. When using the IPM capital
cost model, retrofit difficulties
associated with an SCR may result in
capital cost increases of 30 to 50% over
the base model.200
199 Andover Technology Partners, ‘‘Cost of NO
X
Controls on Wyoming EGUs’’, October 28, 2013;
Wyoming EGU BART and Reasonable Progress
Costs—10/28/2013.
200 Sargent & Lundy, ‘‘IPM Model—Revisions to
Cost and Performance for APC Technologies SCR
Cost Development Methodology FINAL’’, August
2010, Project 12301–007, Perrin Quarles Associates,
Inc. p 1.
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A proper estimation of retrofit factors
involves more than an inspection of
satellite images. For example, EPA
Region 8 visited the four-unit Colstrip
power plant in Montana before
concluding that a retrofit factor of ‘‘1’’
was appropriate. Once such a site visit
is conducted, retrofit factors should be
developed for each element of the cost
analysis—not the ‘‘blanket’’ approach
used by EPA here.
Another example is provided by
Sargent & Lundy’s ‘‘Constructability
Review’’ for addition of SCR at Navajo
Generating Station. Navajo Generating
Station consists of three EGUs, with the
middle unit constrained by a coal
conveyor passing through. Even so,
Sargent & Lundy estimated that
construction effort would be only 25%
greater for Unit 2 than for the other two
units. EPA needs to clarify why they
chose to add a retrofit factor greater than
1 (average retrofit factor of 1.33 for 13
of 15 units reviewed) to the costs when
retrofit costs are already contained
within data used to generate the IPM
and when neither Wyoming, Basin
Electric, or PacifiCorp included a
comparable retrofit factor. By adding the
retrofit factor, EPA has overestimated
the costs of SCR: in the case of Dave
Johnston Units 1, 2, and 4 and Wyodak
Unit 1, this has led EPA to propose lessefficient controls than SCR.
Chapter 2, ‘‘Cost Estimation: Concepts
and Methodology’’ of the CCM provides
a lengthy discussion of retrofit factors.
The CCM addresses SCR retrofits
specifically ‘‘A correction factor for a
new installation versus a retrofit
installation is included to adjust the
capital costs’’ (Section 4, NOX Controls,
Section 4.2, NOX Post- Combustion,
Chapter 2, SCR). The CCM retrofit factor
is $728/MMBtu/hr and, for medium-size
boilers like Dave Johnston Unit 4 or
Wyodak, this represents a 23%–24%
increase in the direct capital cost.
EPA inconsistently and without
explanation applied ‘‘retrofit factors’’
that improperly increase the reported
capital costs of SCR installation. Such
retrofit factors are intended to account
for the increased costs of unusually
difficult retrofits, i.e., those that present
more challenges than assumed for the
‘‘typical’’ SCR retrofit, for which costs
are described by the IPM SCR cost
module. The EPA unjustifiably
determined that only two of the fifteen
Wyoming EGUs (Laramie River Station
Units 1 and 3) would be of average
difficulty, while applying increases of
between 20 and 50 percent to the
remaining units. The EPA applied such
retrofit factors even for units for which
the source owners did not claim aboveaverage installation challenges. The
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EPA’s exclusive evidence of potential
retrofit challenges—satellite images—
does not support the EPA’s application
of retrofit factors. (The commenter
submitted a TSD that elaborated on
some of these points.)
The descriptions given of the EPA’s
view of the retrofit difficulty at each
plant based on satellite images make it
clear that many guesses were made and/
or that the EPA erred on the side of high
retrofit difficulty to be conservative.
Being conservative in cost estimates
may be acceptable if such conservatism
is applied equally to all units and if the
EPA provides a reasoned basis for its
assumptions, but the EPA did not do so.
The EPA assumed that the two units in
the middle at Jim Bridger ‘‘will be
somewhat more difficult to achieve
access for equipment’’ and applied the
highest retrofit factor of 1.5 to these
units, while for Laramie River Unit 2,
the EPA assumed more retrofit difficulty
due to its location in the middle but
only applied a retrofit factor of 1.2. The
EPA essentially made guesses that the
middle units may have more retrofit
difficulty, and did not consistently
apply the same retrofit factors to the
middle units of these two plants. We
found it telling that PacifiCorp’s capital
cost estimates for installation of SCR
systems at all four Jim Bridger units
(which are of equal size to each other)
were identical for each unit, and the
same is true of Basin Electric’s capital
cost estimates for installation of SCR
systems at all three Laramie River units
(which are also equal in size). Given
these facts, the EPA has no basis for its
application of a higher SCR retrofit
factor for the units in the middle (i.e.,
Jim Bridger Units 2 and 3 and Laramie
River Unit 2).
To summarize, the EPA has not
adequately justified the application of
any retrofit factor to the costs of SCR at
any of the EGUs in Wyoming, and the
EPA should not apply retrofit factors to
increase the capital costs of SCR
without adequate justification for those
retrofit factors. Further, the EPA must
remember that the IPM cost module for
SCR is based on actual cost data for SCR
retrofits, and that virtually all SCR
retrofits would have some space
constraints due to most power plants
being built without ever planning for
SCR installation. The EPA should only
apply a retrofit factor if it can justify
that the cost of SCR installation would
noticeably deviate from a typical
installation.
Response: As noted by commenter,
the IPM cost model is based upon actual
retrofits and incorporates all of the costs
normally associated with retrofit of an
SCR. This means that many of the
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retrofit issues commenters have raised
are incorporated into the base cost,
which can then be adjusted with a
retrofit difficulty factor based upon the
perceived difficulty of the retrofit
relative to typical retrofits. EPA
disagrees with the commenter in its
assertion that the EPA inconsistently
and without explanation applied
‘‘retrofit factors’’ that improperly
increase the reported capital costs of
SCR installation.
EPA applied retrofit factors while
carefully considering site conditions.
Where there was uncertainty, EPA did
lean toward making more conservative
estimates, which would explain the
average retrofit factor exceeding 1.0.
Section 2.5.3.2 of the CCM discusses
retrofit cost considerations as ‘‘Probably
the most subjective part of a cost
estimate.’’ The CCM states that, ‘‘Since
each retrofit installation is unique, no
general factors can be developed. A
general rule of thumb as a starting point
for developing an appropriate retrofit
factor is: The larger the system, the more
complex (more auxiliary equipment
needed), and the lower the cost level
(e.g. study level, rather than detailed),
the greater the magnitude of the retrofit
factor.’’ Thus, retrofit difficulty factor
may factor in some uncertainty and be
higher to account for that.
In the cost estimates EPA developed,
retrofit factors were determined from
satellite images using the following
considerations: (1) Available access to
and from the site for transportation of
equipment and available space for
laying down construction materials; (2)
Location of equipment relative to each
other and whether there is a substantial
amount of demolition necessary in order
to make room for SCR equipment; and
(3) Access for a crane. At a highly
congested site, crane access can be
difficult and may entail a more costly
approach. Access for a crane is a
particular concern for internal units
when units are located side-by-side.
There are no strict guidelines used for
determining the actual value of retrofit
factors. They are a matter of judgment.
Per the CCM at 2.5.4.2 (page 2–28,
Chapter 2 Cost Estimation: Concepts
and Methodology), ‘‘[t]he proper
application of a retrofit factor is as much
an art as it is a science, in that it
requires a good deal of insight,
experience, and intuition on the part of
the analyst.’’ What follows is the
explanation for each of the retrofit
factors used at each of the sites. As will
be shown, the retrofit factors were the
result of a thoughtful process, and were
not arbitrary.
With regard to the Dave Johnson site,
this is one of the more congested sites
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in Wyoming. Per the Andover report on
estimated costs of NOX controls: ‘‘Based
upon the close proximity of the boilers
and associated equipment to one
another, decommissioned chimneys that
will limit access and ability to move a
crane, the coal pile and coal conveyors
that also limits access to the area of the
units where construction would occur,
the office building that is adjacent to
Unit 1 and limits access, and the Unit
4 scrubber, retrofit of an SCR on Units
1–4 would likely entail a significantly
higher than average retrofit cost. Unit 4
probably has the best access of all of the
units because there may be some space
between the boiler and the scrubber, but
it is difficult to say for sure from the
image and therefore a conservatively
high retrofit difficulty was used for unit
4 that is consistent with the other
units.’’ 201 As noted, the site is fairly
congested for all units, justifying a high
retrofit factor of 1.5 for all units, not just
the middle units.
Jim Bridger is also limited on space,
but not so much so as Dave Johnston:
‘‘Based upon the satellite photo, the
SCR reactors would likely be installed
above the ESPs and ductwork routed to
the boiler. The boilers do not appear to
be unusually constrained from the
perspective of installing SCR ductwork;
however, access for construction
equipment will be much more difficult
to achieve for the two middle units. The
scrubbers and associated piping will
limit access somewhat. Unit 4 access
will be limited somewhat by the coal
conveyor and because it’s scrubber takes
up more room than the other scrubbers.
For this reason a retrofit difficulty factor
of 1.5 is assumed for the middle units
and 1.25 for units 1 and 4.’’ 202
On the other hand, as is apparent
from the satellite image, Laramie River
is a more open site than Dave Johnson.
Satellite images ‘‘show a less
constrained site than Dave Johnston,
with good access to both units 1 and 3.
The coal conveyor is clearly visible and
will be an obstruction for the unit 2
SCR. As a result, retrofit difficulty of
installing SCR is expected to be average,
except possibly for unit 2 which is
located between units 1 and 3. Access
of a crane will be somewhat more
challenging for Unit 2 and an SCR
retrofit difficulty of 1.2 is assumed for
estimating SCR capital cost. In all cases
201 Andover Technology Partners, ‘‘Cost of NO
X
Controls on Wyoming EGUs’’, October 28, 2013, p.
30; Wyoming EGU BART and Reasonable Progress
Costs—10/28/2013.
202 Andover Technology Partners, ‘‘Cost of NO
X
Controls on Wyoming EGUs’’, October 28, 2013,
p. 35; Wyoming EGU BART and Reasonable
Progress Costs—10/28/2013.
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the SCR reactor is likely to be installed
above the ESP ductwork.’’ 203
Naughton is much more congested
than Laramie River, although access
appears slightly better than for Dave
Johnson. Per the Andover report:
Babcock & Wilcox provided cost estimates
for the Naughton unit 1 & 2 SCRs. Babcock
& Wilcox’s estimate assumed that it would be
necessary to demolish stacks that will be
abandoned after a planned scrubber
installation and they also determined that
additional fan capacity was not necessary.
Babcock & Wilcox also assumed a complex
support structure would be needed, which
adds cost. Babcock and Wilcox also stated
that units 1 and 2 are slightly offset which
makes it impractical to build a common
support structure for the SCR reactors;
however, . . . Babcock & Wilcox has used a
longer horizontal duct run on the unit 1 SCR
which places the unit 1 and unit 2 SCR
reactors side-by-side so that a common
support structure is likely to be possible,
offering some potential savings from what
they have estimated. Alternatively, a shorter
horizontal duct run on unit 1 may make it
possible to avoid demolition of the unit 1
chimney that will be abandoned. When using
the IPM algorithm a retrofit difficulty factor
of 1.3 is assumed. This was based upon the
fact that it appeared to be a less congested
site than Dave Johnston, but there were
potential challenges, such as the chimneys,
that could result in longer duct runs or
additional demolition.
For unit 3 it is also unclear if there is
enough space to install the SCR reactor on
the same side of the chimney as the boiler,
which, means that demolition of that
chimney may be needed. There appears to be
access for construction equipment, such as a
crane, in the area east of the plant (the upper
part of the photo) and to the north of unit 3.
In estimating the cost of the SCR for unit 3,
retrofit difficulty is above average because
more lengthy duct runs or demolition of the
chimney are likely needed, and an assumed
retrofit difficulty factor of 1.3 is assumed for
unit 3.
In the event SCR were installed at the site,
the SCR reactor would likely be located
above the existing (but decommissioned) ESP
shown between the boiler building and the
chimney . . . There is ample room on the
As a result, the retrofit factors used
were not arbitrary but the result of a
thoughtful process of examining the site
for issues that would affect the difficulty
of the retrofit.
Comment: EPA’s application of the
maximum retrofit factor (1.5) to Dave
Johnston Units 1 and 2 is unsupported
and leads to a significant $1.5 million/
year and $800/ton overestimation of
average costs. Neither PacifiCorp nor
Wyoming proposed a retrofit factor for
these units. It is especially surprising
that EPA has applied the maximum
retrofit factor to all four units at Dave
Johnston, and that even an ‘‘end’’ unit
like Unit 1 is considered to have the
highest degree of retrofit difficulty. It
has been our experience that end units
are typically the easiest to retrofit, while
the more difficult retrofits are associated
with ‘‘middle’’ units. Once the SCR
costs are corrected to address the issue
discussed above, the incremental costs
become $5,700–$5,800/ton (versus
$7,050/ton at Bridger Unit 2).
The EPA applied a retrofit factor of
1.5 to Dave Johnston Units 1–3, citing
close proximity of boilers,
decommissioned chimneys and the coal
pile. It is not clear that these issues
warrant a 50 percent increase in SCR
costs due to retrofit difficulty at Units
1–3.
Response: EPA’s estimate of retrofit
factor is based upon a thoughtful
consideration of the various factors
described in the previous response.
With regard to the Dave Johnston site,
this appears to be one of the more
difficult sites in Wyoming from the
perspective of retrofit.
Comment: EPA’s application of the
maximum retrofit factor (1.5) to SCR on
Dave Johnston Unit 4 is unsupported
and leads to a significant $3.8 million/
year and $900/ton overestimation of
average costs. Neither PacifiCorp nor
Wyoming proposed a retrofit factor for
this unit. We disagree with EPA’s
decision to apply the maximum retrofit
factor to all four units at Dave Johnston,
and that even an ‘‘end’’ unit like Unit
4 is considered to have the highest
203 Andover Technology Partners, ‘‘Cost of NO
X
Controls on Wyoming EGUs’’, October 28, 2013,
p. 39; Wyoming EGU BART and Reasonable
Progress Costs—10/28/2013.
204 Andover Technology Partners, ‘‘Cost of NO
X
Controls on Wyoming EGUs’’, October 28, 2013,
p. 52; Wyoming EGU BART and Reasonable
Progress Costs—10/28/2013.
Hence, Naughton is assumed to be an
above average retrofit difficulty because
of the potential for some significant
interference from some equipment and
the possible need for longer than
average duct runs.
For Wyodak, access to the site appears
good, but there are some possible issues
that might come up if the existing (but
decommissioned) ESP needs to be
demolished, which was the reason for
the above average retrofit factor of 1.3.
Per the Andover report:
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site for lay down of material. Location of a
crane near the construction site appears to be
possible; however, in every direction from
the boiler there is a potential interference
that might complicate crane location relative
to the lay-down area. Therefore, the difficulty
of this retrofit is probably average to perhaps
above average. A conservative estimate of
retrofit difficulty of 1.3 is assumed, although
a closer examination of the site may show
that a lower retrofit difficulty may be
possible.204
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degree of retrofit difficulty. It has been
our experience that end units are
typically the easiest to retrofit, while the
more difficult retrofits are associated
with ‘‘middle’’ units.
The CCM retrofit factor is $728/
MMBtu/hr and, for medium-size boilers
like Dave Johnston Unit 4 or Wyodak.
This represents a 23%–24% increase in
the direct capital cost. For Dave
Johnston Unit 4, the EPA applied a
retrofit factor of 1.5 to the costs of SCR
because ‘‘[t]here may be more space
available near unit 4 for a retrofit of
SCR, but this is unclear from the
photograph.’’ This is a very questionable
basis to justify increasing the costs of
SCR by 50 percent.
Response: Because of the congestion
of the overall site at Dave Johnson plant,
a large reduction of retrofit factor to well
below 1.5 was not justified even though
Unit 4 is an end unit. There appears to
be other equipment in the vicinity of
Unit 4 that would obstruct access and
maintaining a retrofit factor of 1.5 seems
reasonable.
Comment: The EPA assigned a 1.3
retrofit factor to the SCR cost estimate
for the single unit Wyodak plant. It
appears the main reason for applying
this factor is because the SCR would
likely have to be placed on top of the
decommissioned ESP, and that space
constraints were not an issue. Although
the EPA summarized that ‘‘. . . the
difficulty of this retrofit is probably
average to above average since it is
common to have some relocation of
equipment,’’ the EPA applied a 30
percent increase to the SCR costs for
Wyodak.
Response: As noted by the
commenter, EPA determined that a
retrofit factor of 1.3 is conservative at
Wyodak. But, because of the possible
items that are apparent (as described
above) from the satellite photograph and
that could get in the way, it was not
regarded as below average difficulty, but
perhaps something slightly above
average. EPA therefore does not believe
that the retrofit factor should be lower
than 1.0 and it may be as high as 1.3.
EPA is basing its cost analysis on the
more conservative estimate.
Comment: In Montana, EPA used the
IPM algorithms for some sources and
not for others, asserting only that use of
IPM ‘‘was intended to ensure that the
direct capital costs reflect the most
recent cost levels seen in the
marketplace’’ and thus did not overestimate costs. 77 FR 57888. EPA also
used IPM for the Arizona FIP but failed
to address how its use was consistent
with either the BART Guidelines or the
CCM. 77 FR 72512 (Dec. 5, 2012). In
Colorado, EPA said the State’s cost
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estimates for Craig Unit 1 deviated from
the CCM but accepted them anyway
because EPA was pleased with a State
law that required emission reductions
from certain other EGUs. 77 FR 76875.
EPA sometimes supplements the CCM
with a rule that installed SCR retrofit
costs must fall between $79/kW and
$316/kW, unless the state justifies a
deviation from this range. North Dakota
SIP, 77 FR 20929; Montana FIP, 77 FR
57889; New Mexico FIP, 76 FR 52388,
52392. EPA has proposed to apply this
rule to the Wyoming SIP and FIP, 78 FR
34738. This cost range is derived from
‘‘industry studies’’ and does not appear
anywhere in the CCM. Supplementing
the CCM with this new requirement is
inconsistent from the terms of the CCM
and BART Guidelines.
Response: We agree that we have used
the IPM control cost algorithms in
various regional haze rulemakings as
noted by the commenter. And as noted
by the commenter, our intent in using
the IPM cost algorithms was to ensure
that our capital cost estimates for SCR
reflect those currently found in the
marketplace. Elsewhere in these
responses to comments, we have
documented in some detail how our use
of the IPM algorithms is consistent with
the BART Guidelines and CCM. We
disagree that we have supplemented the
CCM with a rule that retrofit costs must
fall between $79/kW and $316/kW—
2010 dollars ($81/kW to $324/kW when
escalated to 2013 dollars), which was
the range of actual installed capital costs
found in recent industry studies as cited
in our final rule for North Dakota. In the
North Dakota rulemaking, we used this
information to assess whether costs
supplied to EPA by states or sources
were consistent with those observed in
the industry for numerous other retrofits
spanning a wide range of retrofit
difficulties. As such, this in no way
represents a requirement imposed by
EPA; rather, it represents a very
practical means by which EPA has
gauged the validity of costs. We
acknowledge that, given exceptionally
difficult retrofit circumstances or other
factors, it is possible for a particular
retrofit to fall outside of this range. In
fact, we note that our revised costs
supporting this final rule are in some
cases in excess of the cited range. Our
revised SCR costs for BART EGUs, when
represented on a dollar per kilowatt
basis, range from $222/kW to $467/kW,
with a median cost of $322/kW (2013
dollars).205 From this, it is clear that we
205 Andover Technology Partners, ‘‘Cost of NO
X
Controls on Wyoming EGUs,’’ October 28, 2013;
Wyoming EGU BART and Reasonable Progress
Costs—10/28/2013; Wyoming EGU BART and
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have not established a requirement that
SCR capital costs fall within the cited
range as suggested by the commenter.
For our Colorado final action, we are
currently in litigation over our approval
of the State’s BART determination for
Craig.
Comment: EPA inappropriately
claimed that ‘‘Wyoming’s SCR capital
costs on a $/kW basis often exceeded
real-world industry costs’’ (78 FR
34748) and then refers to industry
studies conducted between 2002 and
2007 that report installed unit capital
costs actually incurred by owners
broadly ranging ‘‘from $79/kW to $316/
kW (2010 dollars).’’ Id. EPA also noted
‘‘instances’’ in its proposed FIP ‘‘in
which Wyoming’s source-based cost
analyses did not follow the methods set
forth in the EPA CCM.’’ EPA is simply
incorrect in stating that Wyoming’s
analyses were flawed and did not reflect
real-world industry costs for the units
being analyzed. The commenter states
that they are presenting information on
the ‘‘real-world’’ costs for the upcoming
Jim Bridger Units 3 and 4 SCR projects,
which recently were competitively bid
for engineering, procurement, and
construction contracts to be installed in
accordance with the requirements in the
Wyoming SIP. These real-world costs, in
turn, can easily be compared to the costs
assessed by Wyoming and by EPA in
their BART determinations.
Even when including AFUDC, the
Wyoming SIP cost basis aligns closely
with the EPA’s cost basis, with each
agency again understating real world
costs for these projects. By extension,
this real-world cost information for Jim
Bridger Units 3 and 4 validates the
methodology used by Wyoming to
determine cost information for each of
PacifiCorp’s BART Units. This
information clearly disputes EPA’s
claims in its FIP that Wyoming ‘‘did not
properly or reasonably take into
consideration the costs of compliance’’
and that its SCR cost analyses exceeded
real world industry costs and were
flawed. Id.
Response: We disagree that it was
incorrect for EPA to state Wyoming’s
cost analyses for SCR were flawed. As
discussed in our proposed rule, EPA
found several deficiencies with
Wyoming’s cost analyses, including:
Inclusion of AFUDC, inclusion of some
inappropriate owner’s costs, insufficient
documentation to support vendor
estimates or bids, and use of incorrect
baseline emission rates. 78 FR 34749.
These deficiencies represented a
departure from the procedures outlined
Reasonable Progress Costs for Jim Bridger—10/28/
2013.
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in the CCM and BART Guidelines and,
particularly when taken collectively,
had a material impact on the cost
estimates. We have addressed why each
of these items are inconsistent with the
CCM and BART Guidelines in other
response to comments here.
Moreover, since the time of the State’s
analyses, EPA has been made aware of
additional pertinent information by
commenters, much of which has been
incorporated into the revised costs
presented in this final rulemaking.
Examples include: Inclusion of certain
costs submitted by the facility owner’s
where appropriately documented,
shorter useful life for one facility,
correction for elevation, use of ammonia
instead of urea as SCR reagent, revised
SNCR reagent consumption for some
facilities, and use of busbar costs for
auxiliary power in place of market
prices.
Regarding whether Wyoming’s costs
exceeded real world industry costs, see
EPA’s response to comment
immediately above.
Comment: Wyoming did not
overestimate the costs of SCR. The EPA
claimed to have identified a number of
flaws in Wyoming’s cost analyses for
SCR (78 FR 34748), but only identified
one flaw—that ‘‘Wyoming’s SCR capital
costs on a $/kW basis often exceeded
real-world industry costs.’’ The EPA’s
use of the word ‘‘often’’ indicates that
Wyoming’s costs did not always exceed
real-world costs, but the EPA did not
explain which costs exceeded realworld costs and which did not.
The EPA specifically alleged only that
the cost estimates for Dave Johnston
Units 3 and 4, Naughton Units 1, 2, and
3, and Wyodak ‘‘are in excess of the
range of capital costs documented by
various studies for actual installations,’’
and that the EPA based this conclusion
of five industry studies conducted
between 2002 and 2007. The EPA did
not explain why the State was wrong to
rely on vendor submitted, engineered,
site-specific cost estimates instead of
reports of installations at other facilities
as long as a decade ago. The State’s
costs of compliance are based on sitespecific capital costs, operating costs,
and maintenance costs provided by the
companies in their applications for a
state BART permit, and over 50 percent
of the costs of compliance is driven by
the capital cost to engineer and
physically install a SCR system. Such
costs must be evaluated on a case-bycase basis in accordance with Appendix
Y. Variable costs, including reagent
usage (ammonia), account only for 2 to
7 percent of SCR costs.
The BART Guidelines not only allow,
but encourage states to take into account
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site-specific conditions that impact the
cost of installing emission controls.
Until the EPA explains why it was
unreasonable for Wyoming to prefer
site-specific, real-world costs over
speculative extrapolation of costs
incurred at other facilities many years
past, the EPA cannot lawfully displace
the State’s judgment simply because
EPA prefers one approach over the
other.
Response: We disagree that EPA only
identified one material flaw in
Wyoming’s costs estimates for SCR. See
EPA’s response to comment
immediately above where we identify
several flaws. Because Wyoming’s
approach to estimating SCR costs was
not consistent with the BART
Guidelines and CCM, it was appropriate
for EPA to revise these costs in our
proposed rule.
We agree that the BART Guidelines
encourage states to take into account
site-specific conditions that impact the
cost of installing emission controls.
However, we disagree with the
commenter’s characterization of the
State’s costs of compliance for SCR as
site-specific in nature on the mere basis
that they were submitted by the sources.
There is nothing in the record to
support claims that these costs were in
fact based on detailed site-specific
vendor bids, or are in any manner more
site-specific than those costs relied
upon by EPA in our proposed rule. As
an example, the BART application
submitted by PacifiCorp for Dave
Johnston Unit 3, and relied upon by
Wyoming, states that: ‘‘Costs and
schedules for the LNBs and OFA, SNCR,
and SCR were furnished to CH2M HILL
by PacifiCorp, developed using Sargent
and Lundy’s internal proprietary
database, and supplemented (as needed)
by vendor-obtained price quotes. The
relative accuracy of these cost estimates
is stated by S&L to be in the range of
plus or minus 20 percent.’’ 206
From this, it is clear that PacifiCorp,
and thereby also the State, based SCR
costs on ‘‘S&Ls internal database’’ and
not a unique quotation specific to Dave
Johnston Unit 3 supplied by an SCR
vendor. Moreover, while the BART
application refers to ‘‘vendor-obtained
quotes,’’ it does not make clear for
which items these quotes were obtained,
if any, nor are any quotes for SCR
included in the BART application.
Instead, the total installed capital cost of
SCR (with combustion controls) is
shown in PacifiCorp’s economic
206 Wyoming Regional Haze SIP, Attachment A,
‘‘BART Analysis for Dave Johnston Unit 3,’’
prepared for PacifiCorp by CH2MHILL, December
2007, page 3–7.
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analysis as a single line item with a
value of $83,301,164, but without any
detail or supporting documentation.207
In an update to its initial BART
application, PacifiCorp subsequently
increased the capital cost to
$129,700,000, but again without any
detail or supporting documentation.208
We note that the capital cost estimates
for SCR presented by EPA in our
proposed rule were also based on the
Sargent & Lundy databases as these in
turn underlie the IPM cost algorithms.
As such, the commenter is mistaken
when characterizing Wyoming’s capital
costs as superior to those from EPA.
However, the costs presented by EPA
went on to correct the deficiencies that
we have identified elsewhere (e.g.,
improper calculation of baseline
emissions). Therefore, the capital costs
provided from each agency were
ultimately generated in a similar
manner, but only the overall costs
generated by EPA were in keeping with
the BART Guidelines and CCM.
It is notable that, in order to address
our concerns regarding lack of sitespecific costs and associated
documentation, the Wyoming sources
have submitted additional cost
information during the comment period
for the proposed rule. The PacifiCorp
comments include capital costs based
on a vendor budgetary quote from
Babcock and Wilcox, as opposed to
capital costs based on the Sargent &
Lundy databases. Similarly, Basin
Electric has submitted a consultant’s
report that, while conceptual in nature
and without vendor-based equipment
costs, provides a more detailed analysis
of SCR costs for Laramie River than
before. These submittals contain more
recent and more detailed cost
information than relied upon by
Wyoming in their cost analyses. The
submission of these updated costs from
the sources, intended to supply more
site-specific costs to EPA, belies claims
by the commenter that the costs
originally used by the State were
‘‘vendor submitted, engineered, sitespecific cost estimates.’’
Comment: We would like to point out
that while the EPA makes a point of
saying in their proposed rule that they
have followed their own guidelines in
the CCM, that manual has not been
updated since 2002. Representative
Lummis of Wyoming has authored
207 Wyoming Regional Haze SIP, Attachment A,
‘‘BART Analysis for Dave Johnston Unit 3,’’
prepared for PacifiCorp by CH2MHILL, December
2008, Attachment 1.
208 Wyoming Regional Haze SIP, Attachment A,
‘‘Addendum to Dave Johnston Unit 3 BART
Report,’’ prepared for PacifiCorp by CH2MHILL,
March 26, 2008, Attachment 1.
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language to require the EPA to update
its cost manual for the first time in over
a decade. The old data in the old
handbook no longer reflects the true
costs of designing, engineering and
installing controls. Before rejecting state
data on the cost of compliance, the EPA
must engage states and regulating
entities to acquire real-world cost data
and use that data to update its manual.
Response: We consider the use of the
broader costing methodology used by
the CCM, the overnight method, as
crucial to our ability to assess the
reasonableness of the costs of
compliance. Evaluation of the cost of
compliance factor requires an
evaluation of the cost-effectiveness
associated with the various control
options considered for the facility. A
proper evaluation of cost-effectiveness
allows for a reasoned comparison not
only of different control options for a
given facility, but also of the relative
costs of controls for similar facilities. If
the cost-effectiveness of a control
technology for a particular facility is
outside the range for other similar
facilities, the control technology may be
rejected as not cost-effective. In order
for this type of comparison to be
meaningful, the cost estimates for these
facilities must be performed in a
consistent manner. Without an ‘‘applesto-apples’’ comparison of costs, it is
impossible to draw rational conclusions
about the reasonableness of the costs of
compliance for particular control
options. Use of the CCM methodology is
intended to allow a fair comparison of
pollution control costs between similar
applications for regulatory purposes.
Just as importantly, while we have
followed the broad methodology of the
CCM as required by the BART
Guidelines, we have also accounted for
the cost of controls currently observed
in the marketplace. In particular, our
use of the cost calculations taken from
the IPM, released in 2010, is designed
to reflect modern day costs. Moreover,
operation and maintenance costs for
items such as labor, reagent, and
catalyst, reflect current market values.
In short, we have adhered to the broad
overnight cost methodology specified in
the CCM, while updating both capital
and operation and maintenance costs to
reflect current market conditions.
Therefore, the commenter is mistaken in
asserting that our costs are based on
outdated information.
Comment: EPA’s regional haze FIP
also is improper because it assumes
BART NOX controls over $5,000 per ton
are ‘‘cost effective.’’ (See e.g., 77 FR
33053.) Appendix Y, on the other hand,
states that BART NOX control costs per
ton above $1,500 are not ‘‘cost
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effective.’’ In the preamble to the BART
Guidelines, EPA suggests that 75% of
the EGUs would have BART NOX
removal costs between $100 and $1,000
per ton, and almost all of the remaining
EGUs could install sufficient BART NOX
control technology for less than $1,500
per ton. EPA also recognized in the
preamble that SCR was generally not
cost effective for EGUs, except for EGUs
with cyclone boilers (where the cost per
ton was less than $1,500 per ton, with
an average of $900 per ton). Based upon
EPA’s Preamble, BART NOX control
technology that costs more than $1,500
per ton should not be considered ‘‘cost
effective.’’ Here, EPA found BART NOX
controls with a ‘‘cost effectiveness’’
number much more than $1,500 per ton
to be ‘‘cost effective.’’ Therefore, EPA
should withdraw its regional haze FIP.
Response: We disagree with this
comment. For each source subject-toBART, the RHR, at 40 CFR
51.308(e)(1)(ii)(A), requires that states
identify the level of control representing
BART after considering the factors set
out in CAA section 169A(g), as follows:
‘‘States must identify the best system of
continuous emission control technology
for each source subject to BART taking
into account the technology available,
the costs of compliance, the energy and
non-air quality environmental impacts
of compliance, any pollution control
equipment in use at the source, the
remaining useful life of the source, and
the degree of visibility improvement
that may be expected from available
control technology.’’ 70 FR 39158.
Because the preamble generally
discusses costs, this does not obviate the
need for states (or EPA in the case of a
FIP) to identify the best system of
continuous emission control technology
on a case-by-case basis considering the
five factors. While EPA described
various dollar-per-ton costs as ‘‘costeffective’’ in various preambles (e.g., 70
FR 39135–39136), EPA did not establish
an upper cost effectiveness threshold for
BART determinations.
Comment: Far from stating that the
CCM must be the exclusive source of
cost information, the BART Guidelines
state that ‘‘[t]he basis for equipment cost
estimates also should be documented,
either with data supplied by all
equipment vendor (i.e., budget estimates
or bids) or by a referenced source (such
as the EPA CCM]).’’ Although the BART
Guidelines then say that cost estimates
should he based on the CCM, it also
says that the CCM should only he used
‘‘where possible.’’ The Guidelines go on
to say that the CCM ‘‘addresses most
control technologies in sufficient detail
for a BART analysis.’’
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The CCM does not say that it
addresses ‘all’ control technologies, just
‘‘most’’, implying that the CCM does not
supply all of the necessary information.
Further, the Guidelines state that the
cost analysis should ‘‘take into account
any site-specific design or other
conditions identified above that affect
the cost of a particular BART technology
option.’’ Again, the CCM acknowledges
that there are conditions, design
scenarios, etc. that are not addressed in
the CCM but that exist in the real world
that must be addressed.
Response: We acknowledge that our
BART guidelines state, ‘‘In order to
maintain and improve consistency, cost
estimates should be based on the [CCM],
where possible’’ and that ‘‘[w]e believe
that the [CCM] provides a goodreference tool for cost calculations, but
if there are elements or sources that are
not addressed by the Control CCM or
there are additional cost methods that
could be used, we believe that these
could serve as useful supplemental
information.’’ The CCM contains two
types of information: (1) Study level
cost estimates of capital and operation
and maintenance costs for certain
specific types of pollution control
equipment, such as SCR, and (2) a
broader costing methodology, known as
the overnight method. We agree that the
language of the BART Guidelines does
not require strict adherence to the study
level equations and cost methods used
to estimate capital and operating and
maintenance costs.
We consider the use of the broader
costing methodology used by the CCM,
the overnight method, as crucial to our
ability to assess the reasonableness of
the costs of compliance. Evaluation of
the cost of compliance factor requires an
evaluation of the cost-effectiveness
associated with the various control
options considered for the facility. A
proper evaluation of cost-effectiveness
allows for a reasoned comparison not
only of different control options for a
given facility, but also of the relative
costs of controls for similar facilities. If
the cost-effectiveness of a control
technology for a particular facility is
outside the range for other similar
facilities, the control technology may be
rejected as not cost-effective. In order
for this type of comparison to be
meaningful, the cost estimates for these
facilities must be performed in a
consistent manner. Without an ‘‘applesto-apples’’ comparison of costs, it is
impossible to draw rational conclusions
about the reasonableness of the costs of
compliance for particular control
options. Use of the CCM methodology is
intended to allow a fair comparison of
pollution control costs between similar
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applications for regulatory purposes.
This is why the BART guidelines
specify the use of the CCM where
possible and why it is reasonable for us
to insist that the CCM methodology be
observed in the cost estimate process.
The overnight method has been used for
decades for regulatory control
technology cost analyses, and its use
ensures equitable BART determinations
across states and across sources.
Comment: Although EPA contends
that States must conform in all respects
to the Agency’s CCM, its own consultant
ignores the Manual when calculating
capital costs and operating and
maintenance costs, and instead uses an
entirely different methodology called
the IPM. 78 FR 34749. EPA tries to
finesse this problem by asserting that
the consultant followed ‘‘the structure
of’’ the CCM and BART Guidelines, id.,
but that simply is not true. The IPM is
a fundamentally different tool and uses
a fundamentally different methodology
than the CCM—it does not follow the
CCM. Therefore, to rely on the
consultant’s cost report to disapprove
Wyoming’s cost analysis and BART
analysis would be arbitrary and
capricious, and not in accordance with
law.
Response: We disagree. As noted
elsewhere in these responses to
comments, in our revised cost estimates,
we have followed the broad
methodology of the CCM, referred to as
the overnight method, while updating
capital and operating and maintenance
costs to reflect current real-world costs.
In doing so, we directed our consultant
(Andover) to reconcile anything in the
IPM cost algorithms that would be
inconsistent with the CCM’s overnight
method. For example, the IPM cost
algorithms include AFUDC, which as
we have established elsewhere in these
response to comments, is not part of the
overnight costs. Accordingly, our
consultant eliminated this cost when
utilizing costs derived IPM cost
algorithms. In effect, we have ‘‘squared’’
the IPM-based costs with the
methodology required by the CCM.
Comment: EPA’s average cost
effectiveness for combustion controls
and SCR for the Laramie River units is
higher than Wyoming’s average cost
effectiveness. Compare, e.g., 78 FR
34773, Table 36 (Wyoming’s SCR
average cost effectiveness of $3,372/ton
for Unit 1) with 78 FR 34775, Table 39
(EPA’s SCR average cost effectiveness of
$3.718/ton for Unit 1). The higher the
cost effectiveness of a given technology,
the stronger the case for rejecting it. If
the State was justified in rejecting SCR
based on its lower predicted cost of
SCR, it would be even more justified in
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rejecting SCR if it had used EPA’s
higher cost. The outcome would not
have changed, and so any error alleged
by EPA is not material.
EPA’s incremental cost effectiveness
for combustion controls plus SCR,
compared with the cost effectiveness of
combustion controls plus SNCR, is
lower than Wyoming’s incremental cost
effectiveness. However, in considering
cost effectiveness for purposes of both
its SIP disapproval and its FIP proposal,
EPA cites and relies primarily on the
average cost effectiveness for SCR, not
the incremental cost. 78 FR 34776
(‘‘[T]he cost-effectiveness for new LNBs
with OFA and SCR ranges from
approximately $3600/ton to $3900/ton
with significant visibility improvement
at the most impacted Class I area. . . .
When considering the cost effectiveness
and visibility improvement of new
LNBs plus OFA and SCR, it is within
the range of what EPA has found
reasonable for BART in other SIP and
FIP actions.’’) EPA refers to incremental
cost only incidentally—not as an
affirmative reason for disapproving
Wyoming’s BART. Id. (‘‘We also
propose to find that the incremental
cost-effectiveness does not preclude the
selection of new LNBs with OFA and
SCR.’’).
Response: We disagree. The
commenter fails to note that the
visibility improvement presented by
EPA in our proposed rule is higher than
that found by the State. The tables cited
by the commenter show a visibility
improvement from SCR of 0.44
deciviews resulting from the State’s
analysis, while EPA’s analysis showed a
visibility improvement of 0.79
deciviews. We found that, when
balancing all of the BART factors, this
level of visibility improvement was
significant enough to justify the costs
associated with SCR. In our revised
visibility modeling analysis for this final
rule, we have presented a lower
visibility improvement for Laramie
River Unit 1 of 0.57 deciviews. We
continue to find that this level of
visibility improvement, and
consideration of the other BART factors,
warrants installation of SCR. The same
can be said for the other two Laramie
River units.
Additionally, the SCR costs and
visibility improvement for the Laramie
River units provided by the State and
EPA are not directly comparable. In the
BART application submitted by Basin
Electric, and relied upon by the State,
and unlike in the case of SNCR, no
additional combustion controls are
assumed in the SCR control scenario.
Since the time that Basin Electric
submitted the BART application to the
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State, additional combustion controls
have been installed on the Laramie
River units. We have taken account of
these additional controls in our
analyses. When assessing the emission
reductions from SCR (or SNCR), and the
associated costs and visibility
improvement, we incorporated the
actual emission rates currently being
achieved with the additional
combustion controls. We have presented
the costs of compliance and visibility
for the additional combustion controls
plus SCR, much in the same way that
the State presented the same factors for
the PacifiCorp units.
Comment: The costs of SCR plus
combustion controls are cost effective at
all of the Wyoming EGUs regardless of
whether the costs are based on EPA’s
cost analyses or the commenter’s 2012
cost analyses conducted for the original
Wyoming SIP. SCR costs for each EGU
in Wyoming, show that SCR plus
combustion controls is very cost
effective for all BART-subject EGUs and
also Dave Johnston Units 1 and 2.
Further, even EPA’s June 2013 cost
estimates for SCR plus combustion
controls show that these controls are
cost effective at all Wyoming EGUs,
despite what the commenter believes
are deficiencies in EPA’s cost
effectiveness analyses that overestimate
the costs of SCR plus combustion
controls. These costs are within the
range that has been required or
proposed of other similar sources to
meet BART as follows:
• Final NOX BART determination for
San Juan Units 1–4 requires installation
of SCR at all four units to meet a NOX
emission limit of 0.05 lb/MMBtu, found
that the costs ranged from $1,987/ton to
$2,651/ton of NOX removed, in 2010
dollars.
• EPA Region 9 has proposed SCR as
BART for Four Corners Units 1–5 to
meet a NOX limit of 0.11 lb/MMBtu at
a cost effectiveness of $2,515/ton to
$3,163/ton in 2008 dollars. That
converts to $2,407/ton to $3,028/ton in
2010 dollars.
• In its FIP for Montana, EPA found
that the cost effectiveness of SCR
controls for Colstrip Units 1 and 2 of
approximately $3,200/ton per unit (in
2010 dollars) was reasonable.
• In its FIP for Arizona regional haze,
EPA is requiring SCR along with
combustion controls to meet BART at
the BART-subject coal-fired units at
Apache, Cholla, and Coronado power
plants at cost effectiveness values
ranging from $2,275/ton to $3,472/ton.
Response: We agree that the costs for
SCR plus combustion controls presented
in our proposed rule, taken without
consideration of the remaining BART
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factors, may generally be considered
cost effective. However, the CAA and
RHR require a consideration of all five
BART factors. For example, a control
that is considered cost effective may not
be warranted if the visibility
improvement is minor. Also, there may
be occasions that, while the average cost
effectiveness of a control is reasonable,
the incremental cost effectiveness may
not be. In short, EPA must weigh more
than just the cost effectiveness when
considering BART.
Also note that, as described elsewhere
in these responses to comments, we
have revised the SCR cost estimates that
we presented in our proposed rule. In
today’s final rule, we have again
balanced the costs along with the
remaining BART factors when
considering the selection of BART
controls.
Comment: EPA’s proposed FIP is
arbitrary, capricious, and contrary to
law for a number of reasons, including
that the EPA’s BART analyses ignored
relevant data. Wyoming based its BART
analyses on site-specific, engineered,
vendor submitted bids for installing
emission controls (citing the SIP
Attachment A materials related to
Laramie River Station), and Basin
Electric has submitted to EPA comments
extensively explaining the bases for
these cost estimates, including the
substantial technical difficulty of
installing SNCR and SCR at Laramie
River Station due to the design of the
three units. The EPA has disregarded
the site-specific cost estimates
submitted for Laramie River Station and
the other BART sources in Wyoming,
and the EPA has alleged without any
specificity that Wyoming did not
properly or reasonably take into
consideration the costs of compliance.
The EPA relied on the IPM Model with
retrofit factors adjusted on a source-bysource basis, instead of relying on the
site-specific costs.
EPA’s October 23, 2012 revised cost
memo states that ‘‘[t]he retrofit factor is
a subjective factor used to account for
the estimated difficulty of the retrofit
that is unique to the facility’’ and noted
that these retrofit factors were
determined without site visits, but
based on satellite images of the
facilities. At EPA’s public hearing in
Casper, Wyoming, on July 26, 2013,
Basin Electric’s consultant, Kenneth
Snell, explained to EPA in detail how
the satellite images fail to reveal
multiple conditions specific to Laramie
River Station that make installing SCR
far more expensive than EPA’s
consultant assumed. EPA’s failure to
rebut those positions is arbitrary and,
moreover, that the EPA’s methodology—
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relying on a subjective interpretation of
satellite images—is itself arbitrary and
capricious because it strains credulity to
claim that one can assess retrofit costs
by simply looking at hazy satellite
pictures of a power plant.
Response: EPA disagrees. First,
Wyoming’s BART analysis 209 was based
upon a 2008 cost estimate by Basin
Electric, which, when adjusted for the
fact that they were performed prior to
addition of combustion controls,
resulted in similar capital costs for SCR
and similar cost effectiveness.
Moreover, and as noted in previous
responses, the costs submitted by
Wyoming should not be considered sitespecific estimates, and therefore
superior to EPA’s costs, on the mere
basis that they were submitted by a
source. In any case, with their
comments on EPA’s reproposal, Basin
Electric has roughly doubled their
claimed cost of SCR, but these were not
part of the Wyoming BART analysis.
These new costs submitted by Basin
Electric are presumably intended to be
more site-specific in nature than those
originally submitted to the State.
Second, the new costs offered by
Basin Electric were found to be deficient
in a number of respects that are
discussed more specifically in other
responses to comments. The new costs
estimates included numerous costs that
were inadequately explained or without
any supporting documentation. The
new cost estimates also did not include
vendor quotes. Per Basin Electric’s
Exhibit 14, page 21: ‘‘The LRS [Laramie
River Station] cost estimates are
conceptual in nature; thus, S&L did not
procure equipment quotes specifically
for the LRS control systems.’’
EPA also disagrees with the
commenter regarding the use of satellite
images for assessing retrofit difficulty.
As noted in responses to other
comments, because they provide a
unique ‘‘bird’s eye’’ view, satellite
images are routinely used to evaluate
conditions at a site: Available space for
a crane, access to and from the site,
interferences that may exist at the site
boundary, interferences between major
pieces of equipment, available space for
laying down material. With regard to
SCR installation, satellite images cannot
reveal whether or not the air preheater
must be relocated to accommodate SCR
ductwork; however, none of the
commenters indicated that any affected
Wyoming BART sources found it
necessary to relocate their air preheater.
Satellite images cannot reveal the ‘‘ideal
209 Wyoming Department of Environmental
Quality Air Quality Division BART Application
Analysis AP–6047 May 28, 2009.
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location’’ for reagent storage equipment,
although this is not a large impact on
cost. When possible and resources
allow, site visits may also provide
useful data in addition to satellite
images, but these are generally
performed in addition to rather than in
lieu of analysis of satellite images.
Mr. Snell’s comments are largely
addressed in other comments and
broadly fall into three areas: (1)
Criticism of EPA’s use of the IPM
algorithm for estimating SCR cost; (2)
Assertions that EPA failed to take into
account site-specific factors affecting
cost; (3) Assertions that EPA failed to
take into account balance of plant
systems that would need to be
upgraded. Each of these items raised by
Mr. Snell as well as the specific issues
within each item has been addressed
elsewhere in other responses to
comments.
Comment: It has been our experience
that the effectiveness of SNCR is highly
dependent upon the characteristics of
each boiler. EPA states that SNCR
typically reduces NOX an additional 20
to 30% above combustion controls
without excessive NH3 slip. NOX
reduction with SNCR is known to be
greater at higher NOX emission rates
than lower rates. Accordingly, EPA has
estimated that the NOX reduction from
SNCR as 30% for initial NOX greater
than 0.25 lb/MMBtu, 25% for NOX from
0.20 to 0.25 lb/MMBtu and 20% for
NOX less than 0.20 lb/MMBtu.
To support this statement, EPA cites
a memo from Jim Staudt, Andover
Technology Partners (‘‘Review of
Estimated Compliance Costs for
Wyoming Electric Generating (EGUs)—
Revision of Previous Memo’’, memo
from Jim Staudt, Andover Technology
Partners, to Doug Grano, EC/R, Inc.,
February 7, 2013, p 7), but this memo
provides no evidence or documentation
to support the assumptions that these
control levels can be achieved. Such
assumptions, whether or not supported,
can significantly affect the outcome of a
BART determination, as EPA explained
regarding Laramie River: ‘‘Therefore,
EPA predicts that the reduction that can
be achieved with SNCR at the Laramie
River units is 20%, which is much
lower than the 48% assumed by
Wyoming. This significantly reduces the
tons reduced by SNCR which is in turn
used in the calculation of cost
effectiveness. It also affects the
incremental cost effectiveness between
SNCR and SCR (both in combination
with additional combustion controls).’’
The use of incremental costs in this
manner is extremely sensitive to bias
due to the interjection of control
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5159
strategies based upon invalid
assumptions of control efficiency.
Another commenter stated that the
EPA is wrong to claim that Wyoming
overestimated the ability of SNCR to
reduce NOX. The commenter made the
following points in support of this
claim:
• The CCM claims that ‘‘[r]eductions
of up to 65% have been reported for
some field applications of SNCR in
tandem with combustion control
equipment such as low NOX burners
(LNB).’’
• Wyoming’s estimates are entirely
consistent with demonstrated SNCR
effectiveness. One study clearly
concluded that ‘‘SNCR has the
capability of NOX reductions in the
range of 30–60%, depending on the
specific retrofit application.’’ See EPRI,
Cardinal 1 Selective Non-Catalytic
Reduction (SNCR) Demonstration Test
Program, at 1–2 (2000). That study
showed, for example, that a 600 MW
unit equipped with LNB could reduce
NOX by an amount greater than EPA’s
‘‘typical’’ results.
• The EPA’s AP 42, Fifth Edition,
Volume I, Chapter 1: External
Combustion Sources recognizes that
‘‘[t]he effectiveness of SNCR depends on
the temperature where reagents are
injected; mixing of the reagent in the
flue gas; residence time of the reagent
within the required temperature
window; ratio of reagent to NOX and the
sulfur content of the fuel that may create
sulfur compounds that deposit in
downstream equipment.’’
The commenter concluded that EPA’s
own literature, as well as other studies,
recognize that SNCR effectiveness is
highly contextual and that it can
achieve reductions far in excess of
Wyoming’s estimates.
The commenter asserted that the EPA,
without explanation, disregarded its
own position on the contextual nature
of SNCR effectiveness, and in turn
disregarded Wyoming’s well-reasoned
analysis by relying instead on ‘‘typical’’
NOX reductions. The commenter
believes that the EPA has practiced
arbitrary decision making because the
EPA did not explain in its proposal why
it now prefers a generic approach to
SNCR effectiveness in reducing NOX
over its previously expressed
recognition that effectiveness depends
on a host of facility-specific factors.
Response: EPA agrees with the
commenter that the effectiveness of
SNCR is highly dependent upon the
characteristics of each boiler, and those
characteristics include furnace
temperature, furnace CO concentration,
NOX level and other factors, but furnace
temperature, CO concentration, and
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NOX level are most important. The
tendency of NOX reduction to decrease
as the NOX concentration is reduced is
a well-established phenomenon. Utility
boiler upper furnace temperatures are
typically in the range of 2000–2300 °F,
but can sometimes be lower or higher.
As described in Section 1.2.3, SNCR
Performance Parameters in the Control
CCM, and also by Sun, Hofmann and
Pachaly in 1990, and by Muzio,
Montgomery, Quartucy and Texeira in
1993,210 211 the percentage reduction in
NOX is strongly impacted by the
residence time, furnace temperature and
the starting, or baseline, NOX. Because
most utility boiler furnace temperatures
and residence times fall into an
expected range, the possible NOX
reduction is generally related to baseline
NOX and Figure 1.5 of the CCM
demonstrates the effect of baseline NOX
and temperature on NOX reduction. Of
course, there are some units that may
fall outside the typical range of furnace
temperatures or CO levels, and can
achieve higher or lower levels of NOX
reduction. As noted in our response to
other comments, the furnace
temperatures at Laramie River Station as
reported by Basin Electric in their
recently submitted comments are much
higher than typical, and this will limit
the possible NOX reduction.
On the other hand, EPA disagrees that
EPA ‘‘disregarded its own position on
the contextual nature of SNCR
effectiveness, and in turn disregarded
Wyoming’s well-reasoned analysis’’. On
the contrary, EPA carefully considered
the contextual situation at Laramie
River Station and the State’s analysis in
reaching its opinion. Experience has
shown that for utility boilers NOX
reductions of 48% using SNCR alone
have only been possible from much
higher NOX baselines than exist at
Laramie River Station. In practice,
facility owners have generally found
that, when using SNCR, the lowest cost
approach is to first reduce NOX as far as
possible with combustion controls and
then use SNCR for additional reductions
beyond what combustion controls can
provide. As a result, SNCR is rarely
used alone to provide 48% NOX
reduction on electric utility boilers
because the baseline levels in practice
210 Sun, W., Hofmann, J., and Pachaly, R., ‘‘PostCombustion NOX Reduction With Urea—Theory
and Practice’’, Seventh Annual International
Pittsburgh Coal Conference, September 10–14,
1990.
211 Muzio, L., Montgomery, T., Quartucy, G.,
Texeira, D., ‘‘The Effect of Residence Time On
SNCR Processes’’, EPRI/EPA 1992 Joint Symposium
on Stationary Combustion NOX Control, Bal Harbor,
FL, May 24–27, 1993.
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are typically too low to achieve such
high NOX reduction through SNCR.
The Cardinal Station citation raised
by the commenter is from a test on a 600
MW unit that had a NOX baseline of
around 450–500 ppm of NOX 212—in the
range of about 0.6 to 0.7 lb/MMBtu, well
above the emission rate of the Laramie
River Station units, which, after
additional combustion controls is about
0.19 lb/MMBtu (annual). This unit
achieved 25% NOX reduction at full
load and 30% NOX reduction at 350
MW in long term tests. As a result, this
project does not support the possibility
of 48% NOX reduction with SNCR at
Laramie River Station, which has a
much lower baseline NOX level than at
the Cardinal Station.
Finally, in Exhibit 14 to Basin
Electric’s comments,213 Sargent &
Lundy states that a ‘‘33% reduction is
not likely to be achievable’’ and
conditionally indicates that a 20%
reduction should be achievable from a
baseline emission rate of 0.19 lb/
MMBtu. EPA agrees that based upon the
information that is available, 20% is a
more reasonable level of reduction to
expect from SNCR at Laramie River
Station.
Comment: Contrary to EPA’s
assertion, Wyoming’s estimate of the
reduction achievable with SNCR does
not depart from the BART Guidelines.
The Guidelines do not specify the
effectiveness of SNCR, so there is no
contradiction. EPA observes that
Wyoming assumed that after installation
of combustion controls (new LNBs and
OFA), SNCR would reduce NOX
emissions from 0.23 lb/MMBtu to 0.12
lb/MMBtu, a 48% reduction. EPA,
however, insists that its consultant
contends that SNCR typically reduces
NOX by 20% to 30%, depending on the
level of NOX going to the SNCR unit.
According to EPA’s consultant, when
the input level of NOX is 0.19 lb/
MMBtu, which EPA says was the annual
average at Laramie River Station Unit 1
in 2012, then after installation of new
LNBs and OFA the reduction achievable
with SNCR is only 20%. 78 FR 34748.
The consultant says that would reduce
the NOX emission rate only to 0.15 lb/
MMBtu. Andover Report at 7.
The only authority cited by EPA’s
consultant for the assumed 20%
reduction is an October 15, 2012 email
from Fuel Tech. Id. at 13. No
information is provided by EPA or its
consultant about the expertise of Fuel
212 Stallings, J., ‘‘Cardinal 1 Selective NonCatalytic Reduction (SNCR) Demonstration Test
Program. EPRI Report 1000154, July 2000, pages
4–7 and 8–1.
213 Exhibit 14, pages 15, 16.
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Tech, who at Fuel Tech sent the email,
why an email from Fuel Tech should be
deemed reliable, persuasive or
authoritative, or why it should take
precedence over Wyoming’s analysis.
EPA’s statements in the Montana FIP
demonstrate that EPA’s critique of
Wyoming’s estimate is misplaced. In
that case, EPA determined that with an
inlet concentration of 0.20 lb/MMBtu,
SNCR can reduce NOX emissions by
25%, as compared to the 20% EPA
endorses for a nearly identical inlet
concentration at Laramie River Station.
77 FR 23988, 24023, 24032, 24039; 77
FR 57864, 57885–57886. EPA relied on
information from Fuel Tech to support
the feasibility of a 25% NOX reduction
at this inlet concentration. 77 FR 57885.
EPA explained that: ‘‘[H]igher NOX
reductions can be achieved at mid to
low load heat inputs, possibly up to
40%. Given that the Colstrip Unit 1 and
2 frequently operate at below full load,
it is likely that on an annual basis SNCR
can achieve better than the 25%
emission reduction assumed by EPA.
EPA further explained that its review
of Clean Air Markets Division (CAMD)
emissions data showed that ‘‘there are
many EGUs equipped with SNCR (with
combustion controls) that are achieving
an emissions rate of 0.15 lb/MMBtu or
lower on a monthly basis.’’ Id. at 57886
(emphasis added). For example, Boswell
Unit 4 had a NOX rate of 0.35 lb/MMBtu
with LNB and close-coupled over fire
air (CCOFA). Id. With SNCR and SOFA,
the unit achieved a monthly NOX rate
between 0.11 and 0.14 lb/MMBtu over
a full 12 month period—a reduction of
60% to 69%. Id. In response to
comments that EPA had overstated the
benefits of SNCR, EPA stated that it
would not adopt a higher post-SNCR
emission rate ‘‘without a showing that
there are circumstances unique to
Colstrip Unit 1 and 2 that would
prevent SNCR from achieving the same
reductions as at Boswell Unit 4.’’ Id.
Response: As noted in other
comments, EPA carefully considered the
contextual situation at Laramie River
Station in reaching its opinion. The
Wyoming analysis 214 indicated that
NOX was reduced by SNCR from 0.23
lb/MMBtu to 0.12 lb/MMBtu. This
seemed to be a higher level of NOX
reduction than expected and
inconsistent with other experience. The
BART analysis suggests no additional
NOX reduction from OFA versus LNB.
Experience has shown that for utility
boilers NOX reductions of 48% using
SNCR alone have only been possible
214 Department of Environmental Quality, Air
Quality Division, BART Application Analysis, AP–
6047, Laramie River Station, May 28, 2009.
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from much higher NOX baselines than
exist at Laramie River Station, and a
NOX reduction from 0.19 lb/MMBtu (the
NOX emissions rate after installation of
combustion controls) to 0.12 lb/
MMBtu—roughly 37% reduction—is
not likely to be feasible either. In
practice, facility owners have generally
found that, when using SNCR, the
lowest cost approach is to first reduce
NOX as far as possible with combustion
controls and then use SNCR for
additional reductions beyond what
combustion controls can provide. Those
coal-fired utility units that the
commenter states are achieving below
0.15 lb/MMBtu emission rates and are
equipped with SNCR are also using
combustion controls—most often LNBs
and SOFA—that lower the NOX
sufficiently that less than 20% NOX
reduction is necessary to achieve under
0.15 lb/MMBtu.
As a result, SNCR is rarely used alone
to provide 48% NOX reduction on
electric utility boilers because the
baseline levels in practice are typically
too low to achieve such high NOX
reduction through SNCR. In fact, Exhibit
14 to Basin Electric’s comments, Sargent
& Lundy states that ‘‘33% reduction is
not likely to be achievable’’ and
conditionally indicates that 20%
reduction should be achievable from a
baseline emission rate of 0.19 lb/
MMBtu. This is more consistent with
what EPA has determined.
EPA also cited input from SNCR
technology supplier, Fuel Tech, which
supports EPA’s opinion that an
expected NOX reduction would be in
the range of 20%. Fuel Tech is the
largest supplier of SNCR technology to
the electric utility industry and is
therefore a very knowledgeable source
of information on SNCR.
Comment: Wyoming did not
underestimate the usage and cost of
urea, and its estimate regarding urea
does not conflict with the BART
Guidelines. EPA contends that producer
prices for urea have increased over the
past three years and that Wyoming’s
analysis is defective because it does not
take those price increases into account.
EPA, however, cannot use information
not available at the time of Wyoming’s
BART determination to second-guess
that determination. EPA’s own
Guidelines counsel that in making a
BART determination, a state should
consider technologies ‘‘available before
the close of the State’s public comment
period,’’ but explicitly provide that ‘‘in
order to provide certainty in the
process,’’ a state ‘‘need not consider
technologies that become available after
this date.’’ 40 CFR Part 51, App. Y.,
section IV(D)(2)(3) (emphasis added).
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This makes sense. Absent some time
cutoff, a state’s SIP would be in a
constant state of flux, subject to constant
challenge based on ever changing
information and technology not
available to the State at the time it made
its BART determination. This is
particularly true given the amount of
time it takes EPA to review a state’s SIP.
It is also consistent with 40 CFR
51.308(f), which requires states to
reevaluate and revise their regional haze
SIPs every ten years. That regulation
clearly contemplates that states have a
duty to take into account new
information only in connection with the
required periodic SIP revisions—not on
an ongoing basis.
EPA is again overstepping its role in
this process. Wyoming completed its
BART analysis in 2009, more than three
years ago, and it would have been
impossible to incorporate the alleged
urea price increases in that analysis.
Simply put, Wyoming’s BART
determination is hardly arbitrary and
capricious simply because it failed to
take into account alleged urea price
increases some three years after
Wyoming completed its BART analysis.
Wyoming did precisely what the
Guidelines instruct: made a BART
determination based on information
available before the close of its public
comment period. 40 CFR Part 51, App.
Y., section IV(D)(2)(3). To disapprove
Wyoming’s cost analysis based on
information that was not available to
would be to employ a ‘‘gotcha’’
approach that runs contrary to EPA’s
own regulations and counter to EPA’s
commitment to do its job fairly and
objectively. If the urea issue is truly
material, EPA should, at a minimum,
allow Wyoming to consider whether
this new information would affect its
BART determination before
disapproving that determination.
Another commenter made a number
of the same points, stating that changes
in urea prices are not a valid basis for
disapproving the state’s cost analyses,
and even if they were, EPA’s facts are
mistaken. According to the commenter,
the EPA asserted that the BART sources
underestimated the cost of SNCR and
EPA supported this conclusion by
stating that Wyoming underestimated
‘‘SNCR reagent (urea) usage and cost.’’
The commenter indicated that the EPA
did not explain how Wyoming
underestimated urea usage, but the EPA
asserted that ‘‘prices for urea have
increased in the last three years’’ since
Wyoming submitted its plan to EPA.
This commenter finds it remarkable
that EPA would claim that a change in
urea prices in the time since Wyoming
submitted its SIP somehow invalidates
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5161
the SIP, indicating that the time that has
elapsed since Wyoming submitted its
plan to EPA is due in large part to EPA’s
failure to take timely action on
Wyoming’s plan. According to the
commenter, the EPA did not claim that
Wyoming’s analyses were invalid when
Wyoming submitted its plan in January
2011, and the EPA did not explain how
the change in urea market prices led
Wyoming to unreasonable conclusions.
The commenter stated that the EPA
appears to believe that Wyoming and
other states must constantly update
their BART analyses to account for
changing urea market prices up until the
date that EPA takes final action on the
plan. The commenter asserted that
under this theory, the EPA can hold
SIPs hostage, waiting for commodity
prices to change, and then disapprove
SIPs on that basis alone. The commenter
indicated that the EPA cited no legal
basis for this theory.
The commenter noted that the BART
Guidelines expressly acknowledge that
‘‘[i]n order to provide certainty in the
process,’’ states ‘‘need not consider
technologies that become available after
[the close of the comment period on the
state plan] (citing 40 CFR part 51, App.
Y, section IV(D)(2)(3)). The commenter
believes that in order ‘‘to provide
certainty in the process,’’ the EPA
cannot claim that state plans are
perpetually subject to invalidation as a
result of changing commodity prices.
The commenter stated that the State’s
price for urea does not conflict with the
BART Guidelines, and EPA offers no
evidence that its price is more reliable
than the State’s price. Commenter
provided the following additional
statements: Even if urea prices have
increased, assumptions regarding such
prices do not constitute a failure to
follow the BART Guidelines because the
Guidelines do not specify what the price
is or how it should be determined. EPA
relies on its consultant’s report to claim
that prices have increased, but that
report also says that there has been
significant variability in cost. Andover
Report at 7–8. There is no analysis by
the consultant as to whether, given the
cited price variability, the current price
is likely to go up or down in the future
or what the actual cost of urea is likely
to be going forward. The consultant
relies on a single source at a single point
in time to pick a urea price to apply for
the life of an SNCR installation, with no
consideration of the price variability.
The reliability of the resulting price is
no greater than a roll of the dice at Las
Vegas, and EPA offers no explanation
why its consultant’s price is superior to
the State’s price. It is merely different,
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and this is yet another technical issue
upon which EPA is required to defer to
the State’s assessment.
EPA’s consultant modified its initial
report issued in October 2012 in the
revised report issued in February 2013,
purportedly to account for an alleged
change in urea prices. However, the
February 2013 report cites the very same
source for current urea prices as the
October 2012 report. Compare Andover
Report (Oct. 23, 2012) at 7. n.23, EPA
docket cite EPA–R08–OAR–2012–0026–
0081, with Andover Report (Feb. 7,
2013) at 7 n.22, EPA docket cite EPA–
R08–OAR–2012–0026–0086. Both
reports cite the same 10/12/2012 email
from Doug Kirk of Fuel Tech. The
additional 10/15/2012 email from
Jennifer Zagorsky of Potash Corp that is
cited in the October report is deleted
from the February report. There is no
explanation for the change.
Moreover, urea prices are relevant to
operating costs for SNCR but are not
relevant to SCR. If the State’s urea prices
were too low, that would mean the State
had underestimated the cost of SNCR,
which is what EPA claims in its
proposal. 78 FR 34748. Such an
underestimate would have no material
impact on the State’s BART
determination and thus provides no
basis for EPA’s disapproval. Once again,
this is a fact that in retrospect supports
the State’s BART decision, rather than
demonstrating it to be arbitrary. If
Wyoming’s estimate of the cost of SNCR
should have been higher, as EPA
maintains, the higher cost would tend to
add further support for rejecting
SNCR—the more expensive a control
technology, the stronger the reason to
reject it as BART. So if EPA is correct
in claiming the State’s assumed urea
price was too low, it is incorrect in
claiming this made a difference in the
State’s BART determination. A mistake
in a cost assumption, if there was a
mistake, is not a per se reason to reject
a BART determination. Such a mistake
would help support disapproval of a
cost analysis and resulting BART
determination only if it overstated costs
in a material way and thus tended to
make a technology appear significantly
more costly than it actually would be.
If the State rejected SNCR based on an
allegedly too-low cost of urea, perhaps
EPA could argue that the State was
wrong in rejecting SNCR. But EPA
makes no such argument. It asserts only
that its consultant’s urea price is
different from the State’s price. As
explained above respecting SNCR, to
succeed in arguing that the State’s
rejection of SNCR justifies disapproval
of the State’s BART, EPA would, at a
minimum, have to show that the State
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was arbitrary and capricious. The choice
of BART is the prerogative of the State,
and the State is charged with evaluating
and balancing all five BART factors and
deciding how much weight to give to
each factor. EPA may not disapprove the
State’s judgment merely because it
disagrees with the State on what is a
reasonable cost, or how the State
balanced costs with other BART factors.
In fact, nothing in EPA’s proposal takes
issue with how Wyoming weighed or
balanced the BART factors, or with the
State’s judgment regarding the terms of
the settlement agreement on which the
State’s BART determination for Laramie
River was based. EPA’s complaint is not
with the State’s judgment in applying
the BART factors. Rather, it is that the
State used information with which EPA
disagrees. But that cannot justify
disapproval of the State’s cost analysis
or BART determination.
Another commenter argued that the
information EPA relied on to conclude
that urea market prices have increased
is itself outdated, noting that the report
EPA cited as support for its urea price
claim was completed October 23, 2012,
and relied on vendor emails from Fuel
Tech and PotashCorp dated October 12,
2012 and October 15, 2012, respectively,
to conclude that urea cost
approximately $650 per ton. The
commenter pointed out that the same
report recognizes that ‘‘there has been
significant variability in [urea] cost,’’
and added that since the date of that
report, urea prices have continued to
vary significantly, falling by roughly 50
percent.215 The commenter noted that in
its February 2013 revised cost analyses,
EPA acknowledged the beginning of the
price decrease, pegging urea costs at
$450 per ton. The commenter added
that urea prices are today far closer to
Wyoming’s price assumptions than
EPA’s, which commenter stated were
among the highest prices for urea in the
last four years. Therefore, the
commenter asserted, even if changes in
commodity prices following SIP
submission were a valid basis for
disapproving SIP analyses that relied on
prices at the time of SIP development,
the EPA is factually mistaken to claim
that Wyoming unreasonably
underestimated urea prices; rather, the
EPA has unreasonably overestimated
urea prices by supporting its analysis
with an abnormally high price that is
not reflective of the current market.
Response: We agree that a change in
the market price of urea, in and of itself,
215 Citing PotashCorp., Market Data, August 14,
2013, which can be found at https://
www.potashcorp.com/customers/markets/market_
data/prices.
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may have not provided EPA sufficient
grounds for rejecting the State’s SNCR
analysis. However, we identified a
number of deficiencies in our proposed
rule, that when taken collectively, led
EPA to conclude that Wyoming’s
consideration of the costs of compliance
and visibility improvement for the EGUs
was inadequate and did not properly
follow the requirements in the BART
Guidelines and statutory requirements.
78 FR 34748. Therefore, regardless of
the market price of urea, EPA would
have reached the same conclusion.
Also, regardless of the cost of urea,
EPA found material errors with the
State’s cost analyses for SNCR that
required that we revise the analysis. In
particular, as described in some detail
in response to other comments, the State
significantly overestimated the ability of
SNCR to reduce NOX at Laramie River
Station. There, the State assumed that
SNCR would reduce NOX by 48%. In
response to comments above, EPA has
definitively established, using
information from a number sources,
including Basin Electric’s own
consultant, as well as a major SNCR
supplier, that SNCR cannot approach
this level of control in the case of
Laramie River Station. As such, it was
appropriate, if not obligatory, for EPA to
revisit the SNCR analysis for Laramie
River Station.
Finally, today we are providing
updated SNCR cost analyses in order to
address information provided by
various commenters. Because we have
taken into consideration input from a
number of commenters when revising
costs, we believe that they represent the
most informed and robust costs for
SNCR presented yet. In particular, we
have revised the costs for Laramie River
to reflect high furnace temperatures and
low reagent utilization (a factor not
considered in Wyoming’s analysis). And
we have also updated the SNCR costs to
reflect the most recently available cost
of reagent as delivered to Wyoming. Our
analyses are consistent with our
response on a similar comment in the
Legal Section of this final action.
Comment: EPA erroneously
calculated urea costs. EPA made two
fundamental and significant errors that
have the effect of overstating the costs
of SNCR, which in turn justified the
EPA’s conclusion that SCR is cost
effective. The errors are as follows:
• EPA mistakenly converted pounds
to tons in its calculation of operation
and maintenance costs for urea. See
EPA’s Revised Cost Analyses for Jim
Bridger Units 1–4—Detailed
Spreadsheet Supporting Analyses (NOXSNCR tab, rows 62–64) (Bridger Costs);
EPA’s Revised Cost Analyses for
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Wyoming Sources—Detailed
Spreadsheet Supporting Analyses (NOXSNCR_0 1_03 tab, rows 62–64) (EPA
Costs). The cost formula multiplies the
urea rate (pounds/hour) times the cost
(dollars/ton) and divides that product
by the source’s megawatt rating to yield
a dollar per megawatt hour cost for urea.
In converting pounds to tons, EPA
mistakenly divided by 1,000, when it
should have divided by 2,000 (the
number of pounds in a ton).
• EPA incorrectly calculated the
water dilution variable for operation
and maintenance costs in urea. See
Bridger Costs (NOX-SNCR tab, rows 62–
64); EPA Costs (NOX-SNCR_01_03 tab,
rows 62–64). EPA’s cost calculation
incorporates the wrong spreadsheet cell
(auxiliary power cost). It should have
instead incorporated spreadsheet cell
for the hourly water rate in thousands
of gallons per hour.
Response: The reagent cost
calculation is correct. The urea rate
(assuming 100% urea) is multiplied by
the cost for 50% by weight urea and is
multiplied by 2 (to account for the fact
that the cost is for 50% by weight urea)
and then divided by 2000 (for the tons
to pounds conversion). The effect is to
divide by 1000, which is the equation
shown. Commenter is correct that there
was an error in the dilution water cost
calculation. The error has been
corrected in EPA’s revised cost
estimates. The error has negligible
impact on the estimated cost of SNCR.
Comment: EPA asserts that it was an
error for Wyoming to evaluate SNCR
using a controlled emission rate of 0.12
lb/MMBtu, which is about a 48%
reduction from 0.23 lb/MMBtu (the rate
without new LNB and OFA). 78 FR
34748. EPA claims that after combustion
controls reduce emissions to 0.19 lb/
MMBtu, SNCR can achieve only a 20%
further reduction, to 0.15lb/MMBtu. Id.,
citing a Fuel Tech vendor report. EPA
declined to accept Wyoming’s
conclusion that SNCR would cut
emissions by 20% to 30%. Id.
This conflicts with EPA’s findings in
the North Dakota FIP. 77 FR 20898. EPA
found that SNCR plus LNB and SOFA
at Coal Creek Station Units 1 and 2
could reduce NOX from a baseline of
0.22 lb/MMBtu to 0.115 lb/MMBtu,
which is a 48% reduction. EPA
explained that after combustion controls
reduced emissions to a degree, SNCR by
itself would cut emissions another 25%,
despite the facility’s claim that SNCR
would achieve only a 20% reduction.
Id., citing a Fuel Tech report.
Response: EPA does not dispute that
SNCR in combination with combustion
controls can reduce NOX by 48% in
some cases. As described in our
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response to other comments, EPA does
not agree that 48% reduction of NOX is
possible at Laramie River Station using
SNCR alone.
Comment: We agree with EPA that on
an annual basis SCR can achieve
emission rates of 0.05 lb/MMBtu or
lower. We recommend that EPA
consider that some coal-fired EGUs are
achieving lower emissions; e.g., our
search of the CAMD database found
seven conventional coal-fired EGUs
averaging 0.04 lb/MMBtu or lower on an
annual basis in 2012. Unlike SNCR, for
SCR the ability to achieve low NOX
emissions is less a function of boiler
characteristics and more a function of
SCR design; it is generally accepted that
SCR can reduce NOX emissions by 80–
90+%. However, the average control
efficiency assumed by EPA for all
Wyoming EGUs was 75% (74% median
value).
The efficiency of NOX removal is
determined primarily by the amount of
catalyst used, as pointed out by Hitachi
in an email from Hitachi to EPA Region
9 regarding SCR at the Navajo
Generating Station. In response to a
question from the EPA on SCR NOX
performance guarantee, Hitachi replied
that a 3 plus 1 SCR design could be
designed to guarantee NOX emissions of
0.05 lb/MMBtu on a 30-day rolling
average. However, Hitachi also stated
that the utility and their engineer need
to determine what margin needs to be
applied to insure the unit is capable of
achieving less than the permit level on
a 30-day rolling average. The EPA stated
that in an engineering study performed
by Sargent & Lundy that with a NOX
permit limit between 0.07 and 0.08 lb/
MMBtu, the SCR would be designed for
0.05 lb/MMBtu. The difference between
0.05 and 0.07 is the margin necessary
for compliance. By underestimating the
efficiency of SCR and potentially
overestimating the efficiency of SNCR,
EPA has overestimated the incremental
costs for SCR.
Response: We agree with the
information provided by the
commenters that SCR technology has, in
some cases, the potential to achieve
emissions of less 0.05 lb/MMBtu
(annual). However, emission limits
associated with BART do not need to
meet the lowest emission rate achieved
with that technology at any coal-fired
power plant. The RHR provides that:
‘‘The determination of BART must be
based on an analysis of the best system
of continuous emission control
technology available and associated
emission reductions achievable for each
BART-eligible source that is subject to
BART.’’ 40 CFR 51.308(e)(1)(ii)(A).
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In determining the controlled
emission level, EPA must consider
emission rates that are practically
achievable in light of routine variations
in operation and understanding that the
SCR must be designed to maintain
emissions below the required limit.
SCRs in the U.S. are typically either 2
plus 1, or 3 plus 1 systems, with two or
three initially full catalyst layers plus a
spare layer for future catalyst additions.
EPA is not aware of, nor has commenter
provided information for, any 4 plus 1
SCR systems operating on coal-fired
utility boilers. Therefore, EPA would
favor more commonly used 2 plus 1 or
3 plus 1 SCR designs rather than the 4
plus 1 system described in commenter’s
citation from Hitachi.
Additionally, the BART Guidelines
state that: ‘‘[i]n assessing the capability
of the control alternative, latitude exists
to consider special circumstances
pertinent to the specific source under
review, or regarding the prior
application of the control alternative’’
(40 CFR Part 51, Appendix Y, section
IV.D.3) and that ‘‘[t]o complete the
BART process, you must establish
enforceable emission limits that reflect
the BART requirements’’. (40 CFR Part
51, Appendix Y, section V). The fivefactor BART analysis described in the
Guidelines is a case-by-case analysis
that considers site-specific factors in
assessing the best technology for
continuous emission controls. After a
technology is determined as BART, the
BART Guidelines require establishment
of an emission limit that reflects the
BART requirements, but does not
specify that the emission limit must
represent the maximum level of control
achieved by the technology selected as
BART.
While the BART Guidelines and the
RHR do not preclude selection of the
maximum level of control achieved by
a given technology as BART, the
emission limit set to reflect BART must
be determined based on a consideration
and weighting of the five statutory
BART factors. Therefore, limits set as
BACT during PSD review, or emission
rates achieved from the operation of
individual facilities under an emissions
trading program (e.g., CAA Interstate
Rule) may provide important
information, but should not be
construed to automatically represent the
most appropriate BART limit for a given
technology.
As noted in our response to other
comments, EPA does not believe that we
have overestimated the performance of
SNCR, nor does EPA believe that the
performance of SCR has been
underestimated.
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Comment: EPA’s errors in calculating
SCR costs resulted in significantly
skewed cost-effectiveness
determinations for every unit analyzed.
EPA overstated the costs per ton of SCR
by between 33 and 99 percent. Although
even EPA’s cost estimates for SCR are
within the range that the EPA
previously has found reasonable, the
revised cost analyses correcting what
the commenter believes are EPA errors
make it clear that SCR is cost effective
for every Wyoming EGU.
Response: Commenter’s assertion that
EPA’s costs are too high is largely based
upon disagreement over the retrofit
factors used, EPA’s inclusion of a
provision for taxes and insurance, and
disagreement with use of 7% interest in
determining the capital recovery factor.
EPA has responded to each of these
issues in other comment responses and
has developed revised cost estimates
that will incorporate changes where
EPA believes the changes are warranted.
Comment: Wyoming has
overestimated the cost of SCR. Wyoming
has not provided justification or
documentation for their cost estimates.
We (the commenter) were not provided
with any vendor estimates or bids, and
Wyoming did not use the CCM, as
recommended by the BART Guidelines.
For example, the cost estimates used by
Wyoming and EPA contained AFUDC,
which is not allowed by the CCM and
has been rejected by EPA Region 8 in
other analyses. As a result, total capital
costs estimated by Wyoming for SCR
exceeded $300/kW at ten of the fifteen
EGUs evaluated. EPA has compiled a
graphic presentation of SCR capital
costs adjusted to 2009 dollars. The EPA
data confirm that SCR capital costs
typically range from $73–$243/kW.
Wyoming has not demonstrated unique
features for the Wyoming EGUs that
would justify cost estimates so much
higher than the range for the industry.
Response: We agree that in some cases
Wyoming has overestimated the cost of
SCR. In order to address the cost
analysis deficiencies noted by the
commenter, EPA has performed revised
cost analyses for EGUs where the cost of
SCR is pertinent. In our revised cost
analyses, we have followed the structure
of the CCM, though we have used the
IPM cost models to estimate direct
capital costs and operating and
maintenance (O&M) costs.
3. Consideration of the Five Factors
Comment: We received numerous
comments that the State followed the
requirements of the RHR and CAA, and
simply did not come to the same
conclusions as EPA. Commenters stated
that Wyoming’s BART determinations
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were based on a consideration of all five
BART factors and that the State weighed
each factor appropriately.
Response: We disagree with this
comment. As discussed in detail in
section VII.C.3.a of our proposed
rulemaking, the EPA identified
numerous issues and errors with the
State’s cost analyses, including the fact
that the State underestimated the cost of
SNCR and overestimated the cost of
SCR; the State overestimated the
emission reductions from SNCR; the
State underestimated the control
efficiency of SCR; the State
overestimated the capital costs for SCR;
and the State allowed for some costs not
allowed by the CCM and thus their cost
analyses did not meet the requirements
of the RHR. 78 FR 34748.
Likewise, for the visibility
improvement modeling, EPA discussed
in detail in section VII.C.3.b of our
proposed rulemaking why the State’s
visibility modeling did not meet the
requirements of the RHR (78 FR 34749).
As stated in our proposed rulemaking,
Wyoming did not consider the visibility
improvement associated with SNCR,
which is clearly in conflict with the
requirements set forth in section
169A(g)(2) of the CAA, as well as in the
implementing regulations, which
require that states take into
consideration ‘‘the degree of
improvement in visibility which may
reasonably be anticipated to result from
the use of such technology.’’ In
addition, it was not possible for EPA, or
any other party, to ascertain the
visibility improvement that would
result from the installation of the
various NOX control options because
Wyoming modeled the emission
reductions for multiple pollutants
together in its SIP. Finally, Wyoming
did not establish baseline emission rates
used for modeling in a manner
consistent with BART Guidelines. That
is, Wyoming did not use ‘‘the 24-hour
average actual emission rate from the
highest emitting day of the
meteorological period modeled (for the
pre-control scenario).’’ 70 FR 39170.
Instead, Wyoming modeled baseline
emission rates reflective of permitted
emission limits, leading to both an
underestimation, and in some cases,
overestimation of visibility impacts.
Therefore, contrary to the commenters
claim, today’s action is the result of
Wyoming’s failure to meet certain
statutory and regulatory requirements,
and not a simple matter of the State and
EPA arriving at different conclusions.
Comment: Wyoming’s BART NOX
determinations for the Naughton power
plant further demonstrate Wyoming’s
consideration and balancing of all five
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factors, including visibility
improvement, and its individualized
consideration for each unit. For
Naughton Units 1 and 2, Wyoming
found that costs of compliance (total
capital costs and cost effectiveness),
power losses (energy impacts) caused by
post-combustion NOX controls,
environmental considerations related to
chemical reagents used with postcombustion NOX controls (non-air
quality environmental impacts), and
visibility improvement information
indicated that LNBs and OFA are BART
NOX. However, for Naughton Unit 3,
based upon its much greater ‘‘visibility
improvement’’, Wyoming determined
that SCR is BART NOX. Wyoming’s
BART NOX analyses across the
Naughton Plant’s three units
demonstrate Wyoming’s consideration
and weighing of all five BART factors,
including the decision to require
different levels of BART NOX controls
across various units at the same plant
when Wyoming determined that the
visibility improvements and other
factors at one unit justified more
stringent control. This example is yet
one more indication, contrary to EPA’s
assertions, that Wyoming did
adequately consider ‘‘visibility
improvement’’ information in each of its
BART determinations, including
Wyoming deciding in its discretion the
‘‘weight and significance’’ appropriate
for each BART factor at each BART unit.
Response: We disagree with the
commenter’s assertion that the State’s
determination for the Naughton units
shows how the State considered all five
factors when the information that the
State was relying on was not accurate as
pointed out in our response above.
Comment: PacifiCorp submitted its
BART studies to Wyoming in 2007, and
the State completed its BART analyses
during 2008. At that time the remaining
useful life of all PacifiCorp BART units
was considered to be at least 20 years.
Primarily due to EPA’s delays in dealing
with the Wyoming Regional Haze SIP,
this assumed twenty-year life span is no
longer a valid basis for certain units.
EPA now must take into account the
current useful life of the units, rather
than the useful life assumed under
Wyoming’s BART analyses completed at
a different point in time. Dave Johnston
Unit 3’s current depreciable life ends in
2027 and the life for Naughton Units 1
and 2 ends in 2029.
As a practical matter, the SCRs
required under the regional haze FIP at
Dave Johnston Unit 3 and Naughton
Units 1 and 2 could not be installed
until shortly before the end of 2018, due
to the regulatory processes that apply to
PacifiCorp’s major investment
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decisions, as well as the associated
permitting and competitive
procurement timelines. At that time, the
useful life for Dave Johnston Unit 3 will
be nine years, and for Naughton Unit 1
and 2 eleven years. EPA must use these
shorter useful lives in its BART
analyses. Taking into consideration the
remaining useful lives of these
particular BART units clearly
demonstrates that EPA’s current
assessed cost effectiveness conclusions
(whether using the Andover Report
costs or PacifiCorp’s updated
information) do not support the
installation of SCR on these units
because they are not cost effective. To
the extent EPA needs to include firm
retirement dates commensurate with the
depreciable lives for purposes of
finalizing the regional haze FIP, then
PacifiCorp requests that EPA do so.
Response: We agree in part. However,
because of our revised cost and
visibility analyses, and our conclusions
regarding BART that stem from those
analyses, the comment is no longer
pertinent to all of the units in question.
Using a remaining useful life of 20
years, our revised analysis for Naughton
Unit 1 shows that the cost effectiveness
of new LNBs with OFA and SCR is
$3,109/ton, while the incremental cost
effectiveness is $10,384/ton. The
visibility improvement associated with
new LNBs with OFA and SCR is 0.33
deciviews. Similarly, using a remaining
useful life of 20 years, our revised
analysis for Naughton Unit 2 shows that
the cost effectiveness of new LNBs with
OFA and SCR is $2,566/ton, while the
incremental cost effectiveness is $8,440/
ton. The visibility improvement
associated with new LNBs with OFA
and SCR is 0.42 deciviews. Given these
costs and visibility improvements, taken
along with the other BART factors, we
no longer find that SCR is warranted for
Naughton Units 1 or 2, even assuming
a longer remaining useful life.
Therefore, because the commenter
suggested alternative control options in
lieu of the proposed SCR, which we
would otherwise not require, the
comment is no longer pertinent to these
two units. However, as described below,
it remains relevant to Dave Johnston
Unit 3.
Using a remaining useful life of 20
years, our revised analysis for Dave
Johnston Unit 3 shows that the cost
effectiveness of LNBs with OFA and
SCR is $2,635/ton, while the
incremental cost effectiveness is $7,583/
ton. The visibility improvement
associated with new LNBs with OFA
and SCR is 0.51 deciviews. Given these
costs and visibility improvement, taken
along with the other BART factors, we
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continue to find that SCR would be
warranted for Dave Johnston Unit 3.
However, using a remaining useful life
of 9 years, as identified by PacifiCorp,
our analysis shows that the cost
effectiveness of LNBs with OFA and
SCR is $3,742/ton, while the
incremental cost effectiveness is
$11,781/ton. Given the costs that result
from the shorter remaining useful life,
along with other BART factors, we find
that SCR is not warranted. As a result,
we find that combustion controls (LNBs)
and an earlier retirement date are BART
for Dave Johnston Unit 3.
We note that depreciable life is the
result of financial accounting rules,
such as for tax purposes, and is
determined by capital investments in
the plant and associated accounting
rules for the timing of depreciation of
those capital investments. As a result,
the depreciable life is often shorter than
the economic life of the facility.
Economic life, which is the actual
expected viable life of the facility, is the
key consideration in regard to the
remaining useful life (one of the five
BART factors). As a result, depreciable
life is not relevant to a BART analysis
unless the depreciable life that results
from a capital investment for BART is
longer than the economic life of the
facility, in which case asset impairment
charges could result at the end of the
economic life. Nonetheless, we
understand PacifiCorp’s comment as
meaning that, for financial reasons, they
would prefer to shutdown the units on
an accelerated schedule in lieu of
installing SCR.
Finally, while PacifiCorp has
presented revised cost information
along with their comments, we have not
accepted these costs without
examination. As described in other
responses, while allowing some of the
costs suggested by PacifiCorp, we have
not allowed others. More information
regarding our cost analyses for the units
in question can be found in the cost
report located in the docket.216
Comment: In its proposed rule, the
EPA found that the limits and
technologies mandated in the rule are
cost effective based on amortizing those
costs over a 20 year period. Here, the
Agency’s cost modeling is seriously
flawed as many of the units subject to
the new rule have remaining lives
significantly less than 20 years. For
example, Dave Johnston has a remaining
life of only 14 years and Naughton 16
216 Andover Technology Partners, ‘‘Cost of NO
X
Controls on Wyoming EGUs’’, October 28, 2013;
Wyoming EGU BART and Reasonable Progress
Costs—10/28/2013; Wyoming EGU BART and
Reasonable Progress Costs for Jim Bridger—10/28/
2013.
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years. Amortizing the larger investment
required by the FIP over these shorter
lives would cause rates to go up even
more, casting doubt on the veracity of
the EPA’s conclusion that the FIP is cost
effective.
Response: See response above. We
note, however, that we are using the
remaining useful life periods as
presented by PacifiCorp in the comment
above for Dave Johnston Unit 3, which
differ from this commenter’s numbers
for remaining useful life.
Comment: We received comments
that the State considered the energy and
non-air quality environmental impacts
of compliance when developing the
State’s plan. The commenters went on
to say that it is not apparent that EPA
addressed the energy and non-air
quality impacts in their analyses.
Response: We disagree with this
comment. Throughout our proposed
rulemaking, we consistently
acknowledged that we are proposing to
accept the State’s energy and non-air
quality impacts analysis (e.g. 78 FR
34759). In the State analyses for all
BART sources, it states that the energy
and non-air quality impacts do not
preclude the selection of any of the
control technologies the evaluated for
the BART sources. In weighing all of the
BART factors ourselves, we agree with
this conclusion and adopt it as our
assessment of the energy and non-air
quality impacts.
Comment: There are three types of
energy impacts that should be
considered. These include the energy
associated with operating the controls,
the energy that must be provided when
the unit is removed from service in
order to install the controls, and most
importantly to Wyoming and its
citizens, the energy that must be
replaced when the emissions controls
prescribed for a given unit are not
economically justifiable and result in
accelerated unit retirements and
replacements.
The latter scenario is of particular
concern because the EPA has now
proposed SCR controls for PacifiCorp’s
Naughton Unit 1, Naughton Unit 2 and
Dave Johnston Unit 3. Unlike the
Wyoming SIP, the EPA’s FIP requires
controls that are not expected to be
justifiable and would result in
accelerated unit retirements and
replacements, potential natural gas
conversions, and the associated costs
and socio-economic impacts of
removing major coal-fueled generation
resources from service in areas of
Wyoming that rely heavily on these
facilities.
Response: The commenter raises
concerns about energy impacts,
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specifically: The energy associated with
operating the controls, the energy that
must be replaced when the unit is taken
out of service, and the energy that must
be supplied if the unit is retired in lieu
of addition of controls. The energy
associated with operating the controls
are accounted for in the variable
operating cost of SNCR and SCR. Most
of the construction occurs with the unit
operating, but the unit must be shut
down when ductwork tie-ins are made
to the SCR. Regarding replacement
energy when the unit is taken out of
service, the generation units have
periodic outages of several weeks for
major maintenance items, such as
turbine overhaul where there is
adequate time to make the tie-ins for the
equipment. It is reasonable to assume
that facility owners would schedule
outages for the SNCR or SCR retrofits
during periods when other maintenance
is being performed that requires the unit
to be out of service, and this is what is
commonly done in practice. EPA has
allowed five years after the final rule to
meet the emission limits, which should
provide companies ample opportunity
to schedule retrofit activities during a
normally scheduled outage. As a result,
retrofit of NOX controls would not have
a significant impact on the energy
production of the generating unit.
As for the energy that must be
replaced if a unit is retired, the CAA
and BART Guidelines do not explicitly
require that this impact be taken into
consideration as part of the non-air
quality and energy impacts.
Comment: EPA’s proposed approach
is a myopic effort to focus on only one
portion of what is supposed to be a
multi-faceted decision. Appendix Y
became law after notice-and-comment
rulemaking, and states are justified in
relying on it when crafting their regional
haze SIPs. Indeed, EPA made clear that
the Appendix Y guidelines ‘‘are
designed to help States and others . . .
determine the level of control
technology that represents BART for
each source.’’
BART determinations are composite
decisions, with many facts and data
from each of the five BART factors
playing a role in the ultimate BART
determination as decided by Wyoming.
EPA’s proposal to pluck out a single
BART factor (visibility improvement) as
the sole justification for rejecting
Wyoming’s entire NOX BART
determination for some units is arbitrary
and capricious because it makes a single
factor more important than any of the
others and also more important than the
composite BART determination as a
whole. EPA’s approach also disregards
each of the five BART factors as
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Wyoming evaluated them and ignores
the ‘‘weight and significance’’ of each
factor alone, and in combination with
the others, as Wyoming determined in
its BART decisions.
Response: We disagree with this
comment. The commenter is not correct
in asserting that EPA rejected the State’s
BART determinations for certain
sources based only on a single BART
factor—visibility improvement. EPA’s
rejection of the State’s BART
determination was based on EPA’s
consideration of all five BART factors.
Nowhere in our notice do we indicate
that we are rejecting the State’s BART
determination based solely on the
consideration of visibility improvement.
Moreover, as noted elsewhere in these
responses to comments, we found
several instances in which the State’s
analyses were inconsistent with the
RHR and BART Guidelines, requiring
that EPA revise the State’s analyses.
Comment: Use of the BART
guidelines is only required for sources
located at electric generating facilities
with a total capacity greater than 750
megawatts. See 40 CFR 51.308(e)(ii)(B).
Only three power plants in Wyoming
met these criteria: Basin Electric’s
Laramie River Station, PacifiCorp’s Jim
Bridger, and PacifiCorp’s Dave Johnston
plants. For consistency, and as a matter
of State discretion, Wyoming went
above and beyond the requirements by
following the five-step process for all
BART sources, not solely the three
aforementioned large electric generating
facilities. EPA should commend
Wyoming for taking this approach, not
use it as an excuse for invalidating the
SIP.
Response: We agree that the BART
guidelines are only mandatory under
the regional haze regulations for ‘‘fossilfuel fired power plants having a total
generating capacity greater than 750
megawatts.’’ 40 CFR 51.308(e)(1)(ii)(B).
However, the fact that a state may
deviate from the guidelines for other
BART sources does not mean that the
state has unfettered discretion to act
unreasonably or inconsistently with the
CAA and our regulations. Where the
BART guidelines are not mandatory, a
state must still meet the requirements of
the CAA and our regulations. In other
words, the State must still adopt and
apply the best available retrofit
technology, considering the statutory
factors.
Comment: Based on the erroneous
claims that the SIP incorrectly analyzed
costs, calculated baseline NOX
emissions, and modeled visibility
improvement, EPA proposes a FIP for
eight BART sources in Wyoming. For
each of these sources, EPA proposes to
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approve all of the State’s BART NOX
analyses, except for the cost of
compliance, baseline emissions, and
visibility factors. In other words, EPA
approves the State’s analyses of some
BART factors, but not the others.
EPA, however, does not explain how
it weighed the five BART factors after
substituting its cost of compliance,
baseline emissions, and visibility
modeling for the State’s. For example,
for the Laramie River Station units, EPA
reiterates its disagreement with the
State’s analyses and shows how its
analyses change those factors. 78 FR
34776. But EPA does not explain how
it analyzed those new factor conclusions
in relation to the remaining Wyoming
BART factors that EPA proposes to
approve. For each of the eight BART
units, EPA takes the same approach,
failing to explain how it balanced the
multiple BART factors.
Response: We disagree with this
comment. As stated above, EPA came to
its conclusions on the State’s BART
determinations based on a consideration
of the five factors on an individual
source basis. We considered the
visibility benefits and costs of control
together by weighing the costs in light
of the predicted visibility improvement
and the other BART factors.
Comment: There are no threshold
minimum acceptable cost effectiveness
levels, nor any requirements regarding
how much weight a state must give to
cost factors versus other factors such as
visibility. EPA provides no explanation
regarding what it views as a reasonable
cost factor, or why or how such a factor
should be balanced with visibility
factors.
Response: See response above.
Comment: EPA must consider the
energy that must be replaced when the
emissions controls prescribed for a
given unit are not economically
justifiable and result in accelerated unit
retirements and replacements. This
scenario is of particular concern because
the EPA has now proposed SCR controls
for PacifiCorp’s Naughton Unit 1,
Naughton Unit 2 and Dave Johnston
Unit 3. Unlike the Wyoming SIP, the
EPA’s FIP requires controls that are not
expected to be justifiable and would
result in accelerated unit retirements
and replacements, potential natural gas
conversions, and the associated costs
and socio-economic impacts of
removing major coal-fueled generation
resources from service in areas of
Wyoming that rely heavily on these
facilities.
Response: As noted above, the CAA
and BART Guidelines do not explicitly
require that these impacts be taken into
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consideration as part of the non-air
quality and energy impacts.
Comment: EPA’s assertion that
Wyoming underestimated the ability of
SCR to reduce NOX was arbitrary. The
EPA cited no legal or factual support for
its assertion (at 78 FR 34748) that SCR
can achieve emission rates of 0.05 lb/
MMBtu or lower on an annual basis.
EPA approved Colorado’s use of a 0.07
lb/MMBtu annual emission rate for SCR
at coal-fired power plants because the
EPA explained (at 77 FR 76871, 76873)
that rate ‘‘is within the range of actual
emission rates demonstrated at similar
facilities in EPA’s Clean Air Markets
Division (CAMD) emission database.’’
EPA also said in that Colorado action
that an emission rate as low as 0.05 lb/
MMBtu can be achieved only ‘‘in some
cases[.]’’ In its proposed disapproval of
Wyoming’s SIP, the EPA has not
explained why Wyoming’s analyses are
distinct from Colorado’s.
Response: We disagree. In fact, the
cost analyses submitted by both
PacifiCorp and Basin Electric in
comments support EPA’s assumption
that 0.05 lb/MMBtu is achievable on an
annual basis. PacifiCorp’s comments
include a budgetary price estimate for
three units from Babcock & Wilcox
indicating an outlet NOX rate of 0.04 lb/
MMBtu.217 Though Babcock & Wilcox
does not specify the averaging time
basis of this rate, because emission rates
are lower over longer averaging times,
the emission rate would only be lower
if not already expressed on an annual
basis. Similarly, the report prepared for
Basin Electric by Sargent & Lundy
indicates an annual emission rate of
0.05 lb/MMBtu for the Laramie River
units.218 Therefore, it does not appear
that either Sargent & Lundy or Babcock
& Wilcox dispute whether SCR is
capable of achieving an annual emission
rate of 0.05 lb/MMBtu. In addition, the
commenter has not provided any
information to substantiate that SCR
cannot achieve an actual annual
emission rate of 0.05 lb/MMBtu.
Further, as noted by other
commenters, information in the CAMD
database reveals that there a number of
coal-fired EGUs retrofitted with SCR
which are achieving actual emissions of
0.05 lb/MMbtu or less on an annual
basis. It is important to note that the
commenter is questioning the annual
emission rate achievable with SCR (0.05
lb/MMBtu) that EPA assumed for the
217 Letter from Babcock & Wilcox Power
Generation Group, Inc., to PacifiCorp Energy, page
3, August 19, 2013.
218 Laramie River Station SNCR and SCR Cost
Estimates, prepared for Basin Electric Power
Cooperative by Sargent & Lundy, Table 1, page 14,
August 26, 2013.
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purpose of calculating cost
effectiveness. By contrast, when
establishing a 30-day emission limit for
SCR, the annual rate must be adjusted
upward to account for: (1) A margin for
compliance, (2) a shorter averaging
period, and (3) start-up and shutdown
emissions. Therefore, EPA agrees that a
30-day rolling average emission limit of
0.07 lb/MMBtu is appropriate for SCR.
In fact, we have approved this emission
limit for Wyoming sources where the
State has required the installation of
SCR. However, we continue to find that
it was appropriate for EPA to use the
anticipated actual annual emission rate,
as opposed to the allowable 30-day
limit, in calculating cost effectiveness.
The approach taken by EPA is
consistent with the BART Guidelines: In
general, for the existing sources subjectto-BART, you will estimate the
anticipated annual emissions based
upon actual emissions from a baseline
period. 70 FR 39167. That is, cost
effectiveness is more appropriately
based on the reduction in annual
emissions, not the change in allowable
emissions.
Finally, we disagree that we have
treated Wyoming in a manner distinct
from Colorado with regard to the control
effectiveness of SCR. As noted by the
commenter, in Colorado we held that
SCR can achieve an annual emission
rate of 0.05 lb/MMBtu. However, in
Colorado we also held that it was
unlikely that an analysis performed
around this rate would have altered the
state’s conclusions regarding BART. For
units where Colorado did require the
installation of SCR (Craig Unit 2,
Hayden Units 1 and 2, and Pawnee),
Colorado established a 30-day rolling
average emission limit of 0.07 to 0.08 lb/
MMbtu. These emission limits are
commensurate with those established in
Wyoming by both EPA and the State for
SCR.
4. Visibility Improvement
Comment: The implementation by
EPA of its NOX FIP is an overreach of
its authority given the record in this
case. In particular, as it relates to the
Laramie River Station, EPA arbitrarily
requires in its FIP the installation of
SCRs to address regional haze. However,
the facts reveal that the installation of
SCRs is not justified because—even
based on EPA’s own calculations—the
visibility improvement that could be
achieved is imperceptible. Nowhere in
EPA’s proposed rule does it evaluate its
FIP as achieving an improvement in
visibility at an individual Class I area
that meets the standard deciview
definition, i.e., a full deciview being
equal to the amount of visibility
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5167
improvement that is detectable by the
human eye. In addition, EPA failed in
its analysis to consider the predicted
change in visibility between control
options and whether the incremental
improvement for a given control is even
perceptible. Conceding these facts, the
imposition of a FIP to achieve an
imperceptible improvement in visibility
is arbitrary and capricious.
Response: We disagree that the
visibility improvements for Laramie
River Station or other BART sources are
de minimis or too small to just justify
the expense of requiring controls. The
BART Guidelines are clear that it is not
necessary for the visibility improvement
of a particular control option to be
above the perceptible threshold. 70 FR
39129.
Even though the visibility
improvement from an individual source
may not be perceptible, it should still be
considered in setting BART because the
contribution to haze may be significant
relative to other source contributions in
the Class I area. Thus, we disagree that
the degree of improvement should be
contingent upon perceptibility. Failing
to consider less-than-perceptible
contributions to visibility impairment
would ignore the CAA’s intent to have
BART requirements apply to sources
that contribute to, as well as cause, such
impairment. The same facts apply to the
commenter’s assertions on incremental
visibility improvement.
In addition, we received numerous
general comments that controls on
sources were not warranted because the
visibility improvement was less than the
perceptible amount of 1.0 deciview, to
which we respond in the same way.
Comment: EPA’s reliance on
cumulative analysis of visibility
improvement is contrary to the CAA.
The aggregate approach EPA is
employing in its proposed rule has been
rejected by the D.C. Circuit. The Court
held that an EPA requirement for a
group consideration of visibility impacts
was not allowed by the CAA. Instead,
EPA must consider all five BART factors
for each source. As the Court explained,
with the cumulative approach, ‘‘it is
therefore entirely possible that a source
may be forced to spend millions of
dollars for new technology that will
have no appreciable visibility
improvement.’’
Response: We disagree that our
consideration of visibility improvement
was contrary to the CAA. Here the
commenter has conflated two separate
issues related to cumulative visibility
analyses. In the D.C. Circuit ruling,
American Corn Growers Ass’n v. EPA,
291 F.3d 1 (D.C. Cir. 2002), the issue
was related to the cumulative visibility
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impacts from multiple sources. There,
the court held that a source may be
unduly required to install controls
because of the emissions from other
sources. By contrast, in the instance
related to our proposed rule, the issue
is related to the cumulative visibility
impact to multiple Class I areas from a
single source. Therefore, there is no
relationship between the approach
rejected by the D.C. Circuit Court and
that used in our assessment of visibility
improvement.
Comment: EPA found that SCR
provided only a 0.36 delta deciview
incremental visibility improvement for
Dave Johnston Unit 3, using EPA
modeling, with an incremental cost of
$7,163.00. 78 FR 34777–34778. EPA
failed to justify in its proposed rule how
a 0.36 delta deciview improvement, or
approximately one-third that humanly
detectible, justifies the tremendous cost
of SCR. Likewise, EPA found that
installing SNCR at Dave Johnston Unit
4 results in an incremental 0.11 delta
deciview improvement. The alleged
incremental visibility benefit of
installing SNCR at Wyodak is 0.12 delta
deciview at an incremental cost of
$3,725. 78 FR 34784–85. EPA provides
no justification for requiring such
tremendous costs for such an
inconsequential visibility improvement
that likely falls within CALPUFF’s
margin of error. EPA’s modeling
approaches are inconsistent because
EPA has determined in other states that
visibility improvements greater than
those used to justify SNCR at Wyodak
are too small or inconsequential to
justify additional pollution controls. See
77 FR 24794 (0.27 deciview
improvement termed ‘‘small’’ and did
not justify additional pollution controls
in New York); 77 FR 11879, 11891
(0.043 to 0.16 delta deciview
improvements considered ‘‘very small
additional visibility improvements’’ that
did not justify NOX controls in
Mississippi); 77 FR 18052, 18066
(agreeing with Colorado’s determination
that ‘‘low visibility improvement (under
0.2 delta deciview)’’ did not justify SCR
for Comanche units). Tellingly, the ‘‘low
visibility improvements’’ that Colorado
found at the Comanche units not to
justify post-combustion NOX controls,
as agreed to by EPA, were 0.17 and 0.14
delta deciview. 77 FR 18066. In
Montana, where EPA issued a regional
haze FIP directly, it found that a 0.18
delta deciview improvement to be a
‘‘low visibility improvement’’ that ‘‘did
not justify proposing additional
controls’’ for SO2 on the source. 77 FR
23988, 24012. Here, EPA’s actions
requiring additional NOX controls based
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on little-to-no additional visibility
improvement are arbitrary and
capricious, especially when EPA did not
require additional NOX controls in other
states based on similar visibility
improvements. This is particularly true
in Montana where EPA had direct
responsibility for the regional haze
program.
Response: As stated elsewhere in our
response to comments, we must
consider the five factors for each facility
when making a BART determination.
Even though one factor (such as
visibility improvement) may be similar
between two units, it must be weighed
in the context of the other BART factors.
In addition, as we discuss in other
response to comments, in accordance
with the BART Guidelines, controls may
be warranted even in instances where
the visibility benefit is less than
perceptible.
We note that, in light of comments
submitted during the public comment
period, we have revised our BART
determinations for the Naughton Units 1
and 2, the Dave Johnston Units 3 and 4,
and Wyodak. See sections III.B and V.D
for a discussion on our consideration of
the BART factors and our BART
determination for these units.
5. PM BART Determinations
Comment: We received comments
that EPA’s BART determinations with
respect to PM emissions from Wyoming
EGUs are flawed. One commenter
pointed out that contrary to the BART
guidelines, EPA failed to propose BART
limits on condensable PM and total PM
(PM2.5 + PM10), focusing instead solely
on filterable PM. Commenters went on
to state that EPA underestimated the
control effectiveness of baghouses,
which should be able to achieve a limit
of 0.010 lb/MMBtu or even lower, and
thus EPA overestimated the costs
effectiveness for baghouses.
Response: We disagree with both
points made in this comment. On the
first point, the BART Guidelines do not
explicitly require that states establish
separate emission limits for condensable
PM.219 However, we do recognize, by
219 The BART Guidelines do not specify that
States must establish a BART limit for both PM10
and PM2.5. The BART Guidelines provide the
following: ‘‘You must look at SO2, NOX, and direct
particulate matter (PM) emissions in determining
whether sources cause or contribute to visibility
impairment, including both PM10 and PM2.5.’’
[Appendix Y to Part 51, section III.A.2.] This
language in the BART Guidelines was intended to
clarify to States that when determining whether a
source is subject to BART, the modeling evaluation
to determine the source’s impact on visibility has
to account for both PM10 and PM2.5 emissions.
There are several instances in which we state in
both the preamble to the RHR, and in the BART
Guidelines that PM10 may be used as indicator for
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merit of the compliance test methods
specified for PM (e.g. EPA Method 5B),
that the BART emission limits in the
Wyoming SIP only pertain to filterable
PM.
On the second point, the commenter
has not provided any data or
information to substantiate that using a
lower limit (i.e., 0.010 lb/MMBtu) for
baghouses would have changed the PM
BART determinations. Given that the
cost effectiveness for baghouses was
generally excessively high, we do not
expect that using a lower limit would
have changed the BART determination.
Using Jim Bridger Unit 1 as an example,
an emission limit of 0.015 lb/MMBtu
results in an emission reduction of 709
tpy, while using an emission limit of
0.010 lb/MMBtu results in an emission
reduction of 829 tpy (calculated in the
same manner as in Wyoming’s BART
determination: 6,000 MMBtu/hr heat
input and 7,884 hours of operation). In
this example, the cost effectiveness of
the new polishing fabric filter was
$8,980/ton, and the incremental cost
effectiveness was $16,396/ton. Given
these costs, we have no reason to
conclude that such a modest difference
in the reduction (120 tpy) would lead to
a meaningful improvement in visibility.
This is particularly true since, on a per
unit mass basis, PM emissions have a
lower visibility impact than SO2 or
NOX. A similar conclusion can be
drawn for other EGUs where baghouses
were considered.
6. Incremental Costs and Visibility
Comment: Wyoming and EPA have
placed undue weight on incremental
costs and incremental benefits.
Wyoming and EPA have essentially
based their BART and reasonable
progress determinations on incremental
costs and incremental benefits. (In
almost every case, Wyoming stated that
the average cost-effectiveness of the
proposed BART technologies for NOX
are all reasonable.) However, in
discussing average and incremental
costs, EPA BART Guidelines explain:
‘‘The average cost (total annual cost/
total annual emission reductions) for
each may be deemed to be reasonable.
However, the incremental cost of the
additional emission reductions to be
achieved may be very great. In such an
instance, it may be inappropriate to
choose control B, based on its high
PM2.5 in determining whether a source is subject to
BART. Neither the RHR nor the BART Guidelines
specify that states must make separate BART
determinations for PM10 and PM2.5. Therefore, we
disagree that we must evaluate separate limits or
disapprove the PM BART determination for the
Wyoming SIP on the basis that a BART
determination for PM2.5 was not made.
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incremental costs, even though its
average cost may be considered
reasonable.’’ Although EPA does not
explain in its BART Guidelines what it
considers ‘‘very great’’ and ‘‘high’’
incremental costs, it goes on to provide
an example of how incremental cost is
calculated, and explains: ‘‘The
incremental cost of Option 1, then, is
$20,000 per ton, 11 times the average
cost of $1,900 per ton.’’
The clear implication of EPA’s advice
in the BART Guidelines is that
incremental costs become a deciding
factor only if they greatly exceed
average costs. Instead, EPA has
determined that incremental costs only
twice the ‘‘reasonable’’ average costs are
excessive. In doing so, EPA ignores the
established fact that pollution control
costs increase exponentially with
control efficiency, which means that
incremental costs will always exceed
average costs.
Response: We disagree with most
aspects of this comment, but do agree
with the commenter that EPA has not
defined what the terms ‘‘very great’’ or
‘‘high’’ mean when pertaining to
incremental costs. We do not agree with
the commenter that the one of the
examples EPA provided in 40 CFR part
51, Appendix Y, should be interpreted
to mean that incremental costs only
become a deciding factor if they greatly
exceed average costs by some magnitude
over twice the average costs. In
addition, incremental costs are to be
considered within the context of the five
factors, including average cost
effectiveness and visibility
improvement. Our BART
determinations reflect the statement in
the BART Guidelines the commenter
referenced in that while average cost
effectiveness may be reasonable, the
EPA determined that the high
incremental costs in some instances
made the selection of more stringent
controls not to be reasonable, when
considered with visibility improvement.
We discuss in each instance our
evaluation of incremental and average
costs and explain our conclusions.
Comment: Incremental visibility
improvement is not mentioned in the
reasonable progress provisions or BART
Guidelines, and EPA cannot create a
new criterion for the sole purpose of
eliminating a control option that is
reasonably cost-effective and would
yield a significant visibility
improvement. If EPA is going to
compare costs and visibility benefits, it
must do so in a transparent and
objective manner, and state its criteria
for acceptance or rejection of a control
strategy. Relatively subjective
statements about costs being ‘‘high’’ or
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visibility improvements ‘‘small’’ are not
sufficient to justify the decisions.
Response: We disagree with this
comment. The RHR states ‘‘When
making this determination [BART Step
5 on visibility impacts], you have
flexibility in setting absolute thresholds,
target levels of improvement, or de
minimis levels since the deciview
improvement must be weighed among
the five factors, and you are free to
determine the weight and significance
to be assigned to each factor.’’ 70 FR
39170. EPA concludes that in exercising
its discretion, a state or EPA may
consider the incremental degree of
visibility improvement, which is a part
of visibility improvement. EPA’s
consideration of incremental visibility
improvement in our proposed action in
Wyoming is also consistent with EPA
actions in other states (e.g., Kansas (76
FR 80754), Nebraska (77 FR 40150), and
Oregon (76 FR 38997)). In comparing
control options and selecting one, it is
natural to compare the visibility
improvement (that is, to compute the
incremental visibility improvement) for
each option.
Comment: EPA in some cases rejected
the best systems of continuous emission
reduction as BART based on a
subjective judgment that the
incremental costs of concededly
superior controls are not warranted by
the visibility benefits they yield.
However, EPA has failed to offer any
rationale for these cost-benefit
determinations, let alone the increment
threshold applied. As a result, EPA’s
conclusions are at odds with the EPA’s
own analysis demonstrating that
installing the most effective controls
will yield needed visibility
improvements.
EPA’s approach is inconsistent with
the purpose of the RHR and the fivefactor BART analysis. The CAA
identifies the elimination of humancaused visibility impairment in Class I
areas as the purpose and required
outcome of the haze program. 42 U.S.C.
7491(a)(1). Congress directed states and
the EPA to impose the best system of
continuous emission reduction on
BART-subject sources, and identifies
BART as the feasible, cost-effective
technology that produces the most
visibility benefits. For NOX emissions at
Wyoming EGUs, EPA’s source-specific
BART analyses uniformly point to SCR
plus combustion controls as the
appropriate technology.
To avoid this result, however, EPA
puts the technologies that it has already
determined are feasible and costeffective through an incremental benefit
filter in which it assesses not just which
control technology makes the most
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visibility improvement, but how much
more progress it makes over the second
best technology relative to their costs.
EPA applies this additional filter
without disclosing what the threshold of
improvement over the next best
technology or the ratio of incremental
improvement to incremental cost has to
be, instead simply declaring that ‘‘the
cost effectiveness value [of SCR] is
significantly higher than [inferior
technology] and there is a comparatively
small incremental visibility
improvement over the [inferior
technology].’’
If haze plans only compel installation
of controls with lower incremental costs
and large incremental benefits
(whatever those might be), then it may
be impossible to reach the goal of
attaining natural conditions in the Class
I areas. This is especially true for
Wyoming, where there are many large
pollutant sources affecting many Class I
areas. The level of visibility
improvement that can be achieved
through reduction of emissions from
any one source might always be deemed
too small to justify the cost of controls,
in which case we will never be able to
eliminate that last increment of haze
pollution because it is too small to
justify. While EPA or states may argue
that additional emissions reductions can
be achieved in the future, the
opportunity to reduce haze-causing
emissions in initial SIPs/FIPs by
requiring BART, as recognized and
directed by Congress in the CAA, is the
best chance to make significant progress
on this pervasive pollution problem.
EPA’s use of the incremental benefit
analysis to eliminate the best pollutionreduction systems does not comply with
the law.
Response: We do not agree with this
comment. As stated above, EPA based
its decisions on the BART
determinations based on a careful
weighing of the five factors, including
average and incremental cost
effectiveness. Much like average cost
effectiveness, EPA has not established a
threshold for incremental cost
effectiveness as each BART
determination is an individual decision
based on the five BART factors. In
accordance with the BART Guidelines,
for each BART-eligible facility, we
considered incremental cost
effectiveness, and when weighed with
the other BART factors, we reasonably
concluded that more or less stringent
controls were not warranted.
7. Other Comments on BART
Comment: The majority of BART
sources were constructed between 1962
and 1977. They have a typical life
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expectancy of 50–60 years. They likely
will be retired before 2064 and replaced
with state-of-the-art power generation
technology and pollution control
equipment. This will be a major factor
in achieving the 2064 natural
background goal for nitrate when these
units are replaced. Thus, there is no
need for controls on these sources now.
Response: While the goal of the
regional haze program is to achieve
natural visibility conditions in all
mandatory Class I Federal areas by
2064, the statute explicitly calls for a
program of reductions over time, and
incremental reasonable progress
towards the long-term goal. The
requirement for states to implement
BART applies during the first planning
period ending in 2018 and is the first
increment of progress. Furthermore, the
remaining useful life of a facility is one
of the five factors considered for BART.
Thus, for example, if a facility has made
a federally-enforceable commitment to
either shut down or change fuels by a
date certain, the shortened useful life of
the facility is incorporated into the cost
analysis as part of the amortization of
total capital costs.
Comment: Wyoming’s SIP is silent
with respect to BART emissions limits
during malfunctions and emergencies.
However, EPA proposes a FIP
requirement that: ‘‘These [BART]
emission limitations shall apply at all
times, including startups, shutdowns,
emergencies, and malfunctions.’’ 77 FR
33061. As EPA has previously noted,
EPA’s proposed FIP requirement for
Wyoming is not required by the RHR:
‘‘Kansas’ inclusion of the startup,
shutdown, and malfunction provisions
as exemptions from the BART emission
rates are not required elements of the
regional haze SIPs to be developed and
submitted by States pursuant to section
169 of the CAA.’’ See 76 FR 52604,
52618. EPA has also stated that ‘‘EPA’s
disapproval of the startup, shutdown,
and malfunction provisions . . . does
not trigger an obligation on the part of
EPA to issue a FIP pursuant to section
110(c) of the CAA, 42 U.S.C. 7410(c).’’
Id.
Yet, EPA proposes to impose a FIP for
startup, shutdown, emergency, and
malfunction emissions for Wyoming
sources despite EPA’s prior statements
that such exemptions do not trigger an
EPA obligation to issue a FIP. EPA’s
proposed action for Wyoming is
arbitrary, unauthorized and unlawful.
Wyoming does not agree with EPA’s
proposal to include emergencies and
malfunctions in 40 CFR 52.2636(c)(2).
Permitted emission limits should reflect
the potential-to-emit (PTE) of a
stationary source. The PTE refers to a
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stationary source’s maximum capacity
to emit under its physical and
operational design. In estimating a
source’s PTE, Wyoming has consistently
only utilized emissions that are
anticipated to occur on a continuous or
regular basis under the source’s physical
and operational design. See United
States v. Louisiana-Pacific Corp., 682 F.
Supp. 1141, 1158 (D. Colo. 1988).
Emissions that occur outside of a
source’s physical and operational design
or, are unplanned, are not included in
PTE estimates, and are addressed
instead in accordance with Wyoming’s
enforcement discretion. The Wyoming
Supreme Court recently upheld
Wyoming’s approach. See Sierra Club v.
Wyoming Depart of Envtl. Quality, 251
P.3d 310, 2011 WY 42 (Wyo. 2011).
Therefore, Wyoming requests that EPA
withdraw its proposed FIP provision
addressing emergencies and
malfunctions.
Response: We disagree with this
comment. The RHR states that ‘‘Section
302(k) of the CAA requires emissions
limits such as BART to be met on a
continuous basis. Although this
provision does not necessarily require
the use of continuous emissions
monitoring, it is important that sources
employ techniques that ensure
compliance on a continuous basis.’’ 70
FR 39172. The rule goes on to state that
‘‘[m]onitoring requirements generally
applicable to sources, including those
that are subject to BART, are governed
by other regulations.’’ See, e.g., 40 CFR
part 64 (compliance assurance
monitoring); 40 CFR 70.6(a)(3) (periodic
monitoring); 40 CFR 70.6(c)(1)
(sufficiency monitoring) (70 FR 39172).
Therefore, it is clear that the rule
intended for BART emission limits to be
met on a continuous basis and did not
provide either explicitly or implicitly
exceptions for startup, shutdown, or
malfunction. Furthermore, it has been
EPA’s longstanding position that SIP
provisions generally cannot contain
automatic exemptions for startup,
shutdown, and malfunction.220 With
respect to PTE, the comment does not
identify how the arguments about PTE
are relevant to a BART emissions limit.
Finally, regarding claims of
inconsistency with the final action for
Kansas, commenter quotes from the
proposed not the final agency action. As
explained in the final agency action,
EPA did not take final action on those
220 See for example, EPA’s September 20, 1999,
guidance, ‘‘State Implementation Plans: Policy
Regarding Excess Emissions during Malfunctions,
Startup and Shutdown,’’ cited in the next footnote.
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portions of the Kansas submittal, the
state withdrew them.221
Comment: The EPA’s proposed FIP
states only that subject-to-BART sources
must comply within five years of
adoption of the FIP. This blanket
schedule of compliance for FIP sources
is contrary to the CAA. For one thing,
by its very language, the EPA’s proposed
FIP fails to ensure that subject-to-BART
sources ‘‘procure, install, and operate,
as expeditiously as practicable’’ any
additional controls that may represent
BART as required by the CAA. See 42
U.S.C. 7491(b)(2)(A) and (g)(4). The EPA
only requires that sources comply
within five years, but does not actually
require sources to comply with BART
limits established in the FIP ‘‘as
expeditiously as practicable.’’ Thus,
EPA’s proposed FIP fails to implement
the statute. Furthermore, simply stating
verbatim in the FIP that ‘‘sources shall
comply with the emission limitations
and other requirements of this section
within five years of the effective date of
this rule’’ fails to give force and effect
to the statutory requirements that
221 As EPA Region 7 explained in their final
action 76 FR 80754, 80755–6 (Dec. 27, 2011): ‘‘As
EPA explained in the proposed notice, the Consent
Agreements exempted periods of startup and
shutdown for both Kansas City Power and Light and
Westar Energy from compliance with applicable
emission limits, which were not narrowly defined,
and exempted periods of malfunction for Westar
Energy. EPA proposed to disapprove the
exemptions because they are inconsistent with the
Clean Air Act and EPA’s September 20, 1999,
guidance, ‘‘State Implementation Plans: Policy
Regarding Excess Emissions during Malfunctions,
Startup and Shutdown.’’ Steven Herman, Assistant
Administrator for Enforcement and Compliance
Assurance, and Robert Perciasepe, Assistant
Administrator for Air and Radiation, ‘‘State
Implementation Plans (SIPs): Policy Regarding
Excess Emissions During Malfunctions, Startup,
and Shutdown,’’ September 20, 1999; and 52 FR
(45109 November 24, 1987).
EPA subsequently received a letter from the State
dated December 1, 2011, withdrawing the SSM
provisions in the Consent Agreements in their
entirety from the regional haze SIP. Specifically, the
following four provisions were withdrawn from
EPA’s consideration for approval in the regional
haze SIP:
1. All references to, ‘‘excluding periods of startup
and shutdown’’ in Paragraph 23 of the Kansas City
Power and Light Company regional haze agreement;
2. The reference to, ‘‘excluding periods of startup,
shutdown and malfunction’’ in footnote 1 of
Appendix A to the Westar Energy, Inc. regional
haze agreement;
3. All references to, ‘‘excluding periods of startup
and shutdown’’ in Chapter 9.3.1 of the Kansas
regional haze SIP;
4. And the sentence, ‘‘The Agreements between
KDHE and the affected BART sources currently
exclude emissions associated with startup,
shutdowns, and malfunctions (SSM) in the agreed
upon emission limits’’ in Chapter 9.5 of the Kansas
regional haze SIP.
Since the SSM provisions were withdrawn by the
State, and are therefore no longer before EPA,
neither EPA’s proposed disapproval of these
exemptions, nor the comments on that proposed
disapproval, are relevant to this final action.
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compliance occur as ‘‘expeditiously as
practicable.’’ Here, the CAA is clear that
in mandating ‘‘expeditious’’
compliance, FIPs must ensure that
subject-to-BART sources comply as soon
as possible. In this case, the EPA’s
proposed FIP simply fails to ensure
compliance with BART as soon as
possible. It lacks any concrete dates by
which subject-to-BART sources must
comply, other than to state that sources
must comply within the statutory
maximum compliance date of five years.
However, the CAA is clear that if a
source can comply with BART before
five years, it must comply by that earlier
date. See 42 U.S.C. 7491(g)(4). Simply
deferring to the five-year deadline
undermines the Congressional intent
behind the ‘‘as expeditiously as
practicable’’ provision. It is notable that
the EPA actually required ‘‘expeditious
compliance’’ for Jim Bridger Units 3
and 4.
Response: We have reviewed the
compliance dates for meeting BART
limits that are contained in the SIP.
Given the magnitude of the retrofits
being undertaken, we believe that five
years from the effective date of this final
rule is as expeditiously as practicable.
We note that our compliance dates for
Jim Bridger Units 3 and 4 are based on
the fact that those are the dates in the
State’s SIP which we are approving for
these two units.
Comment: Compliance with the
perceived dictates of the CAA need not
be as inflexible as contemplated in the
EPA’s proposal. By exploring and
employing creative solutions, it is
possible to reduce emissions to satisfy
the CAA while ensuring reasonable
value and more cost-effective
expenditures for PacifiCorp’s ratepayers.
Two recent examples of successful
creative alternatives that will save
ratepayers many millions of dollars
include the recent proposals of (1)
Public Service of New Mexico for its
San Juan Generating Station, and (2)
PacifiCorp regarding its Naughton Unit
3 in Wyoming.
Notably, the EPA’s revised 2013
proposal for Wyoming implicates ten of
PacifiCorp’s coal-fueled units. Given the
number of affected PacifiCorp
generation plants, Wyoming appears to
be a particularly fertile ground for
encouraging the type of alternative
solution that satisfied the CAA with
regard to San Juan and Naughton Unit
3. We urge the EPA, in response to these
comments, to signal its willingness to
consider all feasible compliance options
that PacifiCorp may offer (including
those that the EPA has no authority to
order) to provide the lowest-cost
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solution for ratepayers in achieving
emissions reductions.
Response: We agree with the
commenter’s points that there is some
flexibility under the CAA to meet the
requirements of the RHR. As with past
actions, EPA is willing to consider
alternatives compliance proposals that
are put forth.
Comment: Wyoming’s regional haze
program has been underway for several
years. Under EPA’s RHR, BART controls
were expected to be installed by the end
of 2013. Wyoming appropriately and
effectively developed and implemented
a regional haze program that met the
2013 timeline. As required by the
Wyoming SIP, and with the one
exception of Naughton Unit 3 which has
a deadline of 2014, PacifiCorp has fully
implemented Wyoming’s BART
requirements for its Wyoming BART
units. As a result, in 2013 alone, there
will be 76,000 fewer tons of visibility
impairing pollutants emitted by
PacifiCorp BART units than was emitted
in 2004.
Had Wyoming waited for EPA’s final
FIP, none of these reductions would
have occurred to date. In other words,
the Wyoming SIP required regional haze
reductions to begin earlier and extend
over a longer period of time than EPA’s
FIP. It is striking to note that from 2005–
2021 the State’s regional haze program
will have removed 243,000 tons more
NOX from PacifiCorp’s Wyoming
facilities than EPA’s proposed FIP.
In 2022, the EPA’s FIP begins
providing an annual benefit of 5,100
tons per year. Ironically this benefit
only lasts for six years, when the units
at which EPA’s proposed FIP requires
more stringent controls are retired. By
2027, the Wyoming Regional Haze SIP
will have removed over 210,000 more
tons of NOX from PacifiCorp’s units
than the EPA’s proposed FIP, with a
significantly lower cost (more than $300
million less in capital) and will require
significantly lower expenditures in
operation and maintenance between
2022 and 2027.
Response: We acknowledge that the
emission reductions already achieved
by PacifiCorp’s Wyoming facilities are
substantial. However, the emission
reductions already achieved at the
PacifiCorp facilities do not release EPA
from its obligation under the CAA to
review Wyoming’s SIP, or to promulgate
a FIP where we find that the SIP fails
to comply with the CAA or RHR.
We disagree that the SIP will result in
greater emission reductions than the
FIP. As discussed in section III.B, in
response to comments received during
the public comment period, we have
made several changes to our proposed
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BART determinations for the PacifiCorp
units. Even so, our final rule today
continues to achieve greater emission
reductions than the Wyoming SIP for
the PacifiCorp units. For Wyodak, our
BART determination (new LNBs with
OFA and SCR) results in an additional
2,496 tons per year when compared to
the SIP. For Dave Johnston Unit 3,
though PacifiCorp has the option to shut
down the unit in 2027, our BART
determination (new LNBs with OFA and
SCR) results in an additional 1,597 tons
per year when compared to SIP. Clearly,
even though we are no longer requiring
some of the BART controls which we
proposed, the FIP achieves greater
emission reductions than the SIP at any
point in time. Regardless, the BART
determination for any BART source is
founded on a consideration of the
statutory BART factors, and not a
comparison of overall reductions
achieved between a federal and state
plan.
D. BART Sources
1. Basin Electric Laramie River Station
Units 1–3
a. General Comments
Comment: We received numerous
comments expressing concern over the
economic impact our proposed FIP
would have for customers of Basin
Electric, and the commenters urged us
to approve the State’s regional haze SIP.
The commenters went on to point out
that Basin Electric is a non-profit
electric cooperative that must pass costs
on directly to consumers. One
commenter noted that the projected cost
to install SCR for each of the three units
at Laramie River will be $200 million
for Western Minnesota and Missouri
Energy Services members. If that cost is
spread over a 10-year period, the cost
would be $110 million a year, which
relates to an increase in electric rates of
8 percent.
Response: In considering the costs of
compliance, the BART Guidelines
instruct states and EPA to evaluate
several metrics, focusing specifically on
average cost-effectiveness and
incremental cost-effectiveness, not total
capital cost or total annual cost. EPA
has found that the average and
incremental cost-effectiveness of SCR is
reasonable for all three units at Laramie
River. While the BART Guidelines
suggest that total capital cost and total
annual cost, as well as incidental
increases in prices to consumers, can be
considered as part of an affordability
demonstration, Basin Electric did not
provide the necessary detailed
information to suggest that installing
SCR at Laramie River would be
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unaffordable, either for the cooperative
or its rate payers. Consequently, we
believe that our analysis of the costs of
control, which focused on costeffectiveness, was appropriate.
Comment: We received numerous
comments that EPA’s FIP would result
in additional costs of $600–$700 million
for the owners of Laramie River Station
with no perceptible visibility
improvement.
Response: See the response above. We
have addressed the issue of perceptible
visibility improvement in section V.C.4.
As explained in the introductory section
and elsewhere, the visibility
improvements from controls at Laramie
River are significant, even when
considered on a unit by unit basis.
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b. NOX BART Determination
Comment: One commenter provided a
spreadsheet with cost calculations for
each of the affected Laramie River units.
Response: EPA has reviewed the
spreadsheet.222 The major difference in
calculations relates to selection of
retrofit factor and cost of property taxes
and insurance (excluded by
commenter). Commenter indicates that
all facilities have a retrofit difficulty of
1.0. EPA disagrees and has provided our
reasons for retrofit factors in other
comments. In addition, for certain units
where we have incorporated new cost
information submitted by the facility
owner’s during the comment period, we
are no longer applying a retrofit factor.
Finally, property taxes and insurance
costs should be included, but only to
the extent that they are actually
realized. See details in the cost report
included in the docket.223
Comment: EPA’s decision to change
its initial NOX BART proposal for
Laramie River Station Units 1–3 from
SNCR to instead propose requiring SCR
is well-supported by EPA’s analysis.
When site-specific information is
appropriately considered, the costs of
SCR at Laramie River Station are even
lower than EPA estimated. EPA used a
‘‘social interest rate’’ of 7 percent in its
analysis when the plant’s owner used an
interest rate of only 6 percent; the EPA
accepted the owner’s claimed costs of
new LNBs with OFA (after subtracting
disallowed costs), even though other
data submitted by the company
demonstrated lower costs for these
combustion controls; and the EPA’s cost
estimates assumed unreasonably high
auxiliary power costs of $0.06/kilowatt
hour (‘‘kWhr’’), when even the owner
222 Wyoming EGU BART and Reasonable Progress
Costs—10/2013.
223 Andover Technology Partners, ‘‘Cost of NO
X
Controls on Wyoming EGUs’’, October 28, 2013.
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assumed an auxiliary power cost of
$0.015/kWhr in its cost-effectiveness
analyses. Making the suggested cost
changes to the analysis would result in
cost effectiveness values ranging from
$3,244/ton to $3,532/ton, as opposed to
the EPA’s values ranging from $3,589/
ton to $3,903/ton. The substantial
visibility benefits afforded by SCR on
Laramie River Units 1–3 also justify a
finding that SCR is BART on these
units. The costs and visibility
improvements are consistent with what
other states in their SIP or EPA in a FIP
have found reasonable for BART
controls.
Response: EPA has addressed each of
the issues raised by the commenter in
other responses. EPA has provided
revised cost estimates based upon input
and consideration of all commenters.
Comment: The Sargent & Lundy
Evaluation demonstrates that the costs
of installing SCR at Laramie River
Station are excessive and supports
Wyoming’s determination that OFA
plus LNB constitutes BART. In response
to EPA’s proposed SIP disapproval and
FIP, Basin Electric requested that
Sargent & Lundy prepare detailed and
site-specific cost estimates for
installation and operation of SNCR and
SCR at the Laramie River Station.
Sargent & Lundy, ‘‘SNCR and SCR Cost
Estimates, Laramie River Station’’
(August 26, 2013) (S&L Evaluation).
Sargent & Lundy is a leading
engineering, design, and consulting firm
and a system supplier that has extensive
experience with the specification,
evaluation, selection, and
implementation of emission control
technologies and coal-fired power
plants, including more than 98 projects
for the control of NOX emissions. S&L
Evaluation section 2. Indeed, Sargent &
Lundy has participated in the
installation of more than 72 SCR
systems and 26 SNCR systems. Id. The
Sargent & Lundy Evaluation follows the
BART Guidelines and uses the
methodology in the CCM where
possible, while addressing site-specific
variables that are critical to reaching an
accurate cost estimate for these NOX
control technologies at Laramie River
Station.
The Sargent & Lundy Evaluation
estimates that the total capital costs of
SCR would exceed $746 million, while
annual costs of an SCR system for the
Laramie River units would total more
than $86 million. S&L Evaluation,
Tables 3, 7. Total capital costs for
installing SNCR on all three units, on
the other hand, would be approximately
$50.6 million with annual costs of
approximately $20 million. Id. Tables 2,
6. Moreover, the cost effectiveness of
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SNCR based on the Sargent & Lundy
Evaluation would be between $6,967 to
$7,013 per ton of NOX removed. Cost
effectiveness values for SCR range from
$8,531 per ton of NOX removed to
$9,048 per ton of NOX removed, with an
incremental cost effectiveness compared
to SNCR of between $9,157 per ton to
$9,862 per ton. Id. Table 7. The Sargent
& Lundy Evaluation demonstrates that
the costs of installing SCR at Laramie
River Station are excessive and supports
Wyoming’s determination that OFA
plus LNB constitutes BART.
Response: As noted on page 21 of
Exhibit 14 of Basin Electric’s comments:
‘‘. . . Cost estimates prepared for
Laramie River Station are based on
equipment costs and budgetary quotes
available from similar projects and
Sargent & Lundy’s experience with the
design and installation of retrofit SNCR
and SCR control systems. The Laramie
River Station cost estimates are
conceptual in nature; thus, Sargent and
Lundy did not procure equipment
quotes specifically for the Laramie River
Station control systems. Rather,
equipment costs for the Laramie River
Station projects are based on conceptual
designs developed for the control
systems, preliminary equipment sizing
developed for the major pieces of
equipment, and recent pricing for
similar equipment . . .’’
As noted in EPA’s response to other
comments, EPA has found a number of
deficiencies in Sargent & Lundy’s
estimates and disagrees with the costs
they have arrived at for SCR. Also as
described in response to other
comments, in light of recently submitted
information, EPA has accepted Basin
Electric’s estimated capital cost of
SNCR.
Comment: The Sargent & Lundy
Evaluation and resulting cost estimate is
far more accurate than the study level
estimate contemplated by the CCM and
the IPM algorithms relied upon by EPA
in its SIP disapproval and FIP. The
Sargent & Lundy Evaluation takes into
consideration site-specific design and
operating parameters and provides a
conceptual, or scoping-level, estimate
for SNCR and SCR at Laramie River.
S&L Evaluation section 4.5.
The BART Guidelines state that ‘‘cost
estimates should be based on the
OAQPS Control Cost Manual, where
possible’’ and in those cases where the
CCM addresses the control technology
in ‘‘sufficient detail for a BART
analysis.’’ 70 FR 39166. In all cases,
however, ‘‘[t]he cost analysis should
also take into account any site-specific
design or other conditions . . . that
affect the cost of a particular BART
technology option.’’ Id. The CCM
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describes various technologies and
provides general costing methodology,
but EPA acknowledges that the
methodology is intended to provide a
‘‘rough order of magnitude’’ estimate of
costs that is accurate to within ±30%.
CCM section 1.2, page 1–4. This rough
estimate is appropriate for regulatory
development because it can be prepared
at a ‘‘relatively low cost with minimum
data.’’ Id. section 2.2, page 2–3 (internal
quotations omitted). See also S&L
Evaluation at section 4.5. But ‘‘EPA does
not claim cost estimates for industry at
greater than study level accuracy for
industrial users’’ because ‘‘the industrial
user will necessarily have much more
detailed information than the generic
cost and sizing information.’’ CCM
section 2.2, page 2–4, 2–5.
The BART Guidelines may reference
the CCM because it provides a simple
and less costly methodology for
estimating costs, but neither the
Guidelines nor the CCM require use of
a less accurate methodology where more
accurate methodologies are appropriate.
Indeed, the BART Guidelines require
consideration of site-specific variables
that in some cases, such as with SCR,
are not factored into the examples
provided by the CCM. 70 FR 39166.
Under these circumstances, the Manual
‘‘offers the user an opportunity for
greater accuracy than that used by
regulators’’ and gives users the
discretion to ‘‘exercise ‘engineering
judgment’ on those occasions when the
procedures need to be modified or
disregarded.’’ CCM section 1.2, page 2–
4, section 1.3, page 1–7.
The cost estimates prepared by
Sargent & Lundy are scoping-level
estimates, which required the use of
numerous site-specific design
parameters that are not included in the
general CCM equations and reflect all
costs to install the control systems,
taking into account site-specific
variables and physical constraints. S&L
Evaluation section 4.5, Attachments A1,
A2. These estimates are far more
accurate than EPA’s estimates, reinforce
Wyoming’s BART determination, and
demonstrate there is no basis for EPA to
disapprove the State’s action.
Response: We agree that sourcespecific costs can be useful in the BART
analysis and agree with a number of the
cost estimates in the Sargent & Lundy
analysis. However, as noted in our
response to other comments, EPA found
Sargent & Lundy’s estimates of SCR
capital cost deficient in a number of
respects, specifically: (1) Inadequate
explanation for the high labor rates that
were assumed when compared to
published labor rates; (2) High overtime
and per diem costs without sufficient
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explanation; (3) Apparent duplication of
costs associated with General Facilities;
(4) Inclusion of AFUDC; (5) Apparent
duplication of contingencies and other
cost adders; and (6) Addition of
unnecessary SO3 mitigation system. All
of these contributed to excessively high
capital cost. Sargent & Lundy also
assumed excessively high cost for
replacement catalyst, which contributes
to high operating cost.
As described in our responses to other
comments, in light of recently submitted
information, EPA has accepted Basin
Electric’s estimated capital cost of
SNCR.
Comment: The Sargent & Lundy’s
estimate for SCR considers critical sitespecific variables that are not captured
by the CCM. The Sargent & Lundy
estimate for SCR is based on an indepth, detailed study of site-specific
costs conducted by a team of engineers
with extensive experience in SCR
installations. In order to establish SCR
control system design parameters and to
prepare inputs for the capital cost
estimate, Sargent & Lundy engineers
performed a site walkdown to identify
site constraints for the SCRs and
associated plant modifications and
reviewed operating conditions at Units
1 through 3 affecting flue gas conditions
at the SCR inlet. Sargent & Lundy then
developed general arrangement
drawings for the SCRs and new
ductwork, on which estimations for
material quantities were made. Finally,
Sargent & Lundy evaluated the existing
forced draft (FD) fan buildings to
determine whether the existing
buildings could support the SCR
structures based on the conceptual
design.
Sargent & Lundy’s evaluation
identified important design
considerations affecting the SCR cost
estimates, many of them directly related
to the considerations that EPA
acknowledges in the CCM make broad
brush cost estimates for SCR nearly
impossible. CCM section 2.5.4.2, page
2–28 (installation of SCR can ‘‘impose
an addition expense to ‘shoe-horn’ the
equipment into the right locations’’
where ‘‘there is generally little room for
the reactor to fit in the existing space
and additional ductwork, fans, and flue
gas heaters may be needed to make the
system work properly.’’). The
considerations include, inter alia,
congested existing plant configuration,
and limited auxiliary power available at
the station. S&L Evaluation section
4.3.1.
The site congestion at Laramie River
Station substantially complicates
installation of SCR systems because the
location of the FD fan buildings limits
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5173
the open area available to drop support
columns for the SCR. Id. Based on the
site walkdown and review of drawings
provided by Basin Electric, the
conceptual design placed the SCRs
directly above the existing FD fan
buildings, which will require that the
SCR support columns penetrate the FD
fan buildings. This, in turn, would
require the construction of deep
foundations for the SCR support
columns in a congested area resulting in
challenging and time-consuming efforts
to ensure adequate support. Id. Another
related complicating factor relates to
constructability issues. All three units
are constructed side-by-side in a row
with little space between them, which
limits crane placement and would
require selection of larger, more
expensive cranes during installation. Id.
Another major design consideration
identified by Sargent & Lundy is the
need for entirely new auxiliary power
equipment for the SCR and replacement
induced draft (ID) fans because the
existing ID fans currently are running at
full capacity. Id.
In addition, Sargent & Lundy’s
Evaluation took into consideration,
among other factors, the following sitespecific conditions that affect the cost of
SCR at Laramie River Station: (1) Boiler
Building Reinforcement. SCR duct work
will penetrate the existing boiler
building structural columns, thereby
requiring that the boiler building
structural supports be redesigned and
rebuilt and engineered to ensure
continued support of the 20-story boiler
building. (2) SCR Reactors and Catalyst.
The conceptual design calls for two
reactors per unit using anhydrous
ammonia as the reagent. To achieve
required NOX emission reductions on a
consistent basis, three layers of catalyst
would be required and the SCRs would
need to be designed to hold four layers
of catalyst. (3) Ammonia System. The
conceptual design located the
anhydrous ammonia system in a remote
location from the units and, therefore,
the cost estimate assumed that all three
SCR units would share a single
ammonia storage facility. (4) Structural
Stiffening. Structural stiffening of the
ductwork and equipment downstream
of the boiler and upstream of the new
ID fans would be required by federal
regulation to operate at more negative
pressures due to installation of the SCR.
Response: EPA has reviewed the
submitted comments, and believes that
for each of the items cited, insufficient
information was provided to justify why
the cost of SCR at Laramie River Station
would be so much higher than for other
SCRs. Commenter cites the location of
the SCR reactor as an issue. This is an
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issue that is common to every SCR
retrofit. Based upon information used by
EPA and information submitted by
Basin Electric, there is no indication
that location of the SCR reactor will be
any more difficult than at any other site.
In fact, the location is a rather common
location. There was no indication that
major equipment would need to be
relocated. Therefore, in this respect
Laramie River does not appear to be any
more difficult than a typical SCR
retrofit.
Pertaining to site congestion, Laramie
River is no more congested than a
typical facility that retrofits SCR, and in
some respects is less congested. There is
greater difficulty in retrofitting unit 2
(the middle unit), and EPA accounted
for that with a higher retrofit difficulty
factor. Commenter indicates that the
SCR support steel will interfere with
equipment at the ground level,
specifically, the FD fan buildings,
requiring installation of steel and deep
foundations in a congested area. SCRs
are rarely installed at ground level and
are normally installed above other
equipment. SCR support steel is
therefore commonly installed in this
area below the SCR and there typically
is other equipment that interferes with
this. This is not an unusual situation
and is not a reason for SCR cost at
Laramie River Station to be higher than
a typical retrofit. Side-by-side
installation is common, and EPA has
accounted for that with a higher retrofit
difficulty factor for unit 2.
Most boilers are inside a boiler
building and SCRs are always built
outside the boiler building, making it
always necessary to route ductwork
through the boiler building wall or
through the roof. Making penetrations
for SCR ductwork through the boiler
building wall is very common in SCR
retrofits, and this is not a reason to
justify a higher cost for an SCR retrofit
at Laramie River station. SCR reactor 3
plus 1 and in two sections is a common
SCR arrangement for a boiler of this size
and does not justify a higher than
average cost for Laramie River. All SCR
systems have ammonia storage facilities
and typically try to combine storage for
all units at a site together. Ammonia
storage is not a major cost item and
where the system is located on the site
will not make a large difference in
overall cost. Pertaining to the need for
an additional fan, the cost estimate used
by EPA had a specific line item cost for
the fan and associated costs for
electrical and other modifications.
Structural stiffening of ductwork is
typically required when an ID fan is
added. The cost estimate by EPA
included provision for this.
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Notwithstanding these points, EPA has
accepted parts of Basin Electric’s cost
estimate where those costs are
supported. See EPA’s response to other
comments for more information.
Comment: Sargent & Lundy estimated
capital costs based on the conceptual
design of SCR installation at Laramie
River Station and in-depth itemized
studies, not the type of generic cost
factors set forth in the CCM. As a result,
the Sargent & Lundy Evaluation
provides cost estimates that reflect more
accurately the actual costs Basin Electric
would incur for installation of SCR at
Laramie River.
The Sargent & Lundy Evaluation uses
an SCR design with itemized budgetary
cost estimates for major equipment
items and site-specific costs. S&L
Evaluation section 4.5, Attachment A2.
For example, the estimate includes lineitem costs for upgrades, replacements,
or installations of the following plant
subsystems to support SCR operation at
the Laramie River Station: (1)
Foundation work to support SCR
systems; (2) Economizer ductwork
modifications; (3) Larger ID fans will be
required on all three units, requiring
replacement of the existing ID fans; (4)
Existing electrical systems are not
capable of handling the new fan loads
and SCR control systems and will
require significant upgrades; (5)
Structural stiffening of the duct work
downstream of the air heater and
upstream of the new ID fans; (6) The
existing Distributed Control System
needs to be expanded; (7) Dry sorbent
injection control systems will be
required on Units 1 and 2 for SO3
mitigation, resulting from the wet
scrubbers installed on those units; and
(8) Ammonia unloading area
construction, including two storage
tanks and tank equipment, as well as
ammonia delivery and vaporization
equipment.
Because of the site-specific nature of
these items, the assumptions in the
CCM would not be adequate to account
for them, yet these types of system
upgrades add substantial cost to the SCR
installation.
Sargent & Lundy prepared direct
capital cost estimates for each of these
systems, including all costs associated
with equipment, labor, and freight. S&L
Evaluation section 4.5. As EPA
acknowledges, due to the site-specific
nature of SCR, detailed vendor quotes
are difficult to obtain because they
cannot be done in an ‘‘off-the-shelf’’
fashion. CCM section 2.5.4.1, page 2–27.
Sargent & Lundy, however, has used
example vendor quotes for major pieces
of equipment, including ammonia
handling system, unity auxiliary
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transformers, catalyst modules, and
sootblowers and sonic horns, and
adjusted the quotes as necessary to
account for the site-specific factors such
as Laramie River Stations’ boiler size,
flue gas rates, flue gas temperatures, and
inlet and outlet NOX concentrations.
S&L Evaluation section 4.4.1;
Attachment A2. Sargent & Lundy also
provided process equipment cost
estimates for manufactured equipment
in Attachment E of its Evaluation.
Sargent & Lundy estimated material
and commodity costs by multiplying the
quantity of the material needed to
install the system based on the
conceptual design by the unit cost for
the commodity, which was estimated
using Sargent & Lundy in-house data,
vendor catalogs, and industry
publications. Id. section 4.4.2. The basis
for the estimates of materials is set forth
in detail in the Sargent & Lundy
Evaluation. Id. section 4.4.2.1. Labor
costs were estimated based on man-hour
estimates from industry publications,
union craft rates for southeastern
Wyoming, and a local labor productivity
factor. Id. See also id. at Attachment F
(Example Industry Publications—
Commodity Costs and Man-Hour
Estimates). Where the conceptual design
provided insufficient detail on which to
generate an estimated cost, Sargent &
Lundy used allowances based on the
typical scope of similar projects. Id.
section 4.4.3.
Sargent & Lundy considered both
fixed and variable operating and
maintenance costs. S&L Evaluation
section 4.5. Variable costs for SCR
include costs of anhydrous ammonia
and catalyst replacement costs, while
fixed costs include property taxes and
insurance. Id. section 4.5 and Table 5.
Sargent & Lundy’s analysis did not use
the maintenance materials and labor
cost in the CCM of 1.5% of Total Capital
Investment because it results in
significantly higher than expected
maintenance costs than reported by
industry. Rather, Sargent & Lundy used
a lower maintenance materials and labor
cost of 0.25% of Total Capital
Investment, which results in a
conservative estimate of operating and
maintenance costs. Id. section 6.1.2.
Indirect capital costs were estimated
based on total direct capital costs using
the factors set forth in EPA’s CCM. S&L
Evaluation section 4.4.5. For large
projects like SCR, with project durations
of between 1.5 years and four years,
Sargent & Lundy typically would
account for escalation, reflecting the
increases in equipment, material, and
labor costs that occur during the
duration of the project. Id. section
4.4.6.1. Sargent & Lundy has taken a
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conservative approach in its estimate,
however, and has calculated estimates
in constant 2013 dollars without
including escalation, which is
consistent with the constant dollar
approach discussed in the CCM. Id.;
CCM section 4.2, page 2–43.
Response: As noted on page 21 of
Exhibit 14 of Basin Electric’s comments:
‘‘. . . Cost estimates prepared for
Laramie River Station are based on
equipment costs and budgetary quotes
available from similar projects and
Sargent & Lundy’s experience with the
design and installation of retrofit SNCR
and SCR control systems. The Laramie
River Station cost estimates are
conceptual in nature; thus, Sargent and
Lundy did not procure equipment
quotes specifically for the Laramie River
Station control systems. Rather,
equipment costs for the Laramie River
Station projects are based on conceptual
designs developed for the control
systems, preliminary equipment sizing
developed for the major pieces of
equipment, and recent pricing for
similar equipment . . .’’
The approach used by Sargent &
Lundy is essentially how the cost
algorithms for IPM were developed,
upon which EPA relied. Both are
empirically-based estimates that, as
demonstrated in our response to other
comments, use many of the same inputs.
However, Sargent & Lundy developed a
very detailed cost estimate that includes
many line items that would otherwise
be included in the Project Contingency
or other areas, such as General
Facilities, and thereby double-counted
these costs.
EPA has addressed comments relative
to capital cost estimates in our other
responses. EPA has reviewed the
assumed variable operating costs and
has commented on them in other
comments. Regarding fixed operating
costs, the IPM algorithm represents
information from actual facilities, and is
therefore used in EPA’s analysis. As far
as indirect capital costs, EPA agrees that
escalation should not be included
because the CCM requires use of the
overnight method.
Comment: When site-specific
conditions are taken into consideration,
the costs of installing SCR at Laramie
River Station would total nearly $747
million, with annual costs of
$86,074,000. The per unit breakdown of
capital costs are set forth in Table 5 and
Table 3 of the Sargent & Lundy
Evaluation. Direct costs include:
Equipment, material, labor, spare parts,
special tools, consumables, and freight.
Total project costs include equipment
costs for the SCR, ammonia handling
system, and balance-of-plant systems
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including the ID fan, auxiliary power
system, electrical system, and dry
sorbent injection control systems on
Laramie River Units 1 and 2. See S&L
Evaluation section 4. Indirect costs
include: General facilities, engineering
and home office fees, contingencies,
preproduction costs, and initial catalyst
fills. See Cost Manual section 2.5.2,
pages 2–41 through 2–47; S&L
Evaluation section 4.4.5.
In all cases, Sargent & Lundy used
methodology that results in a
conservative estimate of total costs
taking into account the unique, sitespecific factors discussed above. The
Sargent & Lundy Evaluation explains
the effect of these factors on the cost
estimate, consistent with the BART
Guidelines and the CCM. S&L
Evaluation section 5.2.1; CCM section
4.2, page 2–21. In addition, as
acknowledged by EPA’s own consultant,
SCR capital costs have risen
significantly over the past decade. S&L
Evaluation section 5.2.1, citing
Cichanowicz, Edward J., ‘‘Current
Capital Cost and Cost-Effectiveness of
Power Plant Emissions Control
Technologies,’’ (January 2010).
Response: EPA disagrees with
commenter and has identified numerous
deficiencies in the cost estimate
developed by Sargent & Lundy for the
Laramie River Station that are discussed
in previous responses to comments.
Furthermore, the IPM cost algorithm
used had already been adjusted to
address escalation to 2009 dollars and,
per the memo by EPA’s contractor for
this action, the Chemical Engineering
Plant Cost Index (CEPCI) 224 was used to
escalate costs after that period. Per the
memo for the IPM algorithm: ‘‘The data
sets were escalated to update the MOG
information to 2009 and all of the data
was cross referenced with current 2009
projects. The MOG and S&L cost data
were updated to reflect the changes in
equipment and labor rates. The CEPCI
index for power plants was used to
escalate the costs. The Handy-Whitman
index was also used to escalate the
project costs to account for regional
effects; the results were compared with
the CEPCI index and were within 2%
for total project costs.’’ 225
Comment: The Sargent & Lundy
Evaluation considers site-specific data,
including operating parameters for the
Laramie River Station units and design
224 The CEPCI is an industry index that allows for
adjustment of plant construction costs from one
period to another.
225 Sargent & Lundy, ‘‘IPM Model—Revisions to
Cost and Performance for APC Technologies SCR
Cost Development Methodology FINAL’’, August
2010, Project 12301–007, Perrin Quarles Associates,
Inc. p 1.
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parameters for SNCR that were
developed based on input from Basin
Electric and on Sargent & Lundy’s
extensive experience. S&L Evaluation
section 4.1, Table 1. See also id. at
Attachment A1. Prior to undertaking the
cost estimate, Sargent & Lundy
developed a conceptual design taking
into consideration site-specific design
and operating parameters. S&L
Evaluation section 4.2.1. The Evaluation
highlights each of these project-specific
considerations, which include, among
other items: (1) Considerations Related
to Use of Urea as the Reagent. The SNCR
estimate is based on use of urea as a
reagent, which would be delivered by
truck and unloaded into fiberglass
reinforced plastic storage tanks. The
tanks would be cross tied and solution
would be transferred using stainless
steel piping. Centrifugal pumps would
be needed to pump solution to metering
modules and variable frequency drives
would be used to maintain constant
pressure. Finally, distribution modules
would be needed to provide diluted
urea solution and atomizing air to
individual injectors. The design,
quantity, type and placement of
injectors are critical to SNCR
performance. (2) Furnace Modifications.
Penetrations in the boiler water wall
would be required at injector locations;
and to support injector penetrations,
water wall tubes would need to be
removed and replaced with tubes
curved around the location. Also,
reinforcement may be necessary to
support the injectors. (3) Process and
Freeze Protection Tracing System. A
freeze protection system would be
necessary for outdoor piping and
instruments. The system would be
designed to accommodate both normal
plant operations and extended
shutdowns during cold weather. S&L
Evaluation section 4.2.2.
The equipment costs were estimated
based on SNCR original equipment
manufacturers for control systems on
similar coal-fired boilers in light of the
conceptual design of the control
technology. Equipment costs were
developed for SNCR metering skids and
injectors, compressors, reagent storage
tanks, and related ancillary equipment.
Id. section 4.4.1. Consistent with the
SCR cost estimate, material and
commodity quantities for structural,
mechanical and electrical items were
developed for each subsystem included
as part of the SNCR system and
provided as inputs to the cost
calculation. Id. section 4.4.2.1. Material
and commodity pricing was based on
in-house data, vendor catalogs, and
industry publications. Id. Where the
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conceptual design provided inadequate
detail on which to base costs,
allowances were used. Id. section 4.4.3.
Similar to the SCR cost estimate, labor
costs were based on local labor rates,
with an estimate of man-hours required
for installation of each line item in the
SNCR estimate. Id. section 4.4.4.
Indirect capital costs were based on
the CCM, using default factors set forth
in Section 4.2, Chapter 1, Table 1.4. Id.
section 4.4.5. The estimate includes
variable and fixed operating and
maintenance costs, including costs for
urea. Id. section 4.5. Sargent & Lundy
did not include either escalation or
AFUDC in its cost estimate because the
installation of SNCR systems are less
capital and time intensive and can be
done in a shorter period of time than
SCR systems. S&L Evaluation section
4.4.6.3.
Based on methodology consistent
with the CCM, total site-specific costs
for installation of SNCR at Laramie
River Station are approximately $50.5
million, with annual costs of $19.75
million. The breakdown of total costs
per unit can be found at Table 2 of the
Sargent & Lundy Evaluation.
Response: Based upon information
provided by Basin Electric in their
comments, EPA has accepted Basin
Electric’s estimated capital cost for
SNCR and the estimated chemical
utilization.
Comment: The Sargent & Lundy
Evaluation supports Wyoming’s BART
determination. The average
effectiveness of both SNCR and SCR are
high, and the incremental cost of SCR
compared to SNCR is even higher.
Sargent & Lundy calculated the cost
effectiveness of SNCR and SCR
technologies based on emission rates
resulting from Laramie Rivers’
installation of LNB and OFA, consistent
with the BART Guideline’s directive to
use baseline emission rates that
‘‘represent a realistic depiction of
anticipated annual emissions for the
source.’’ 70 FR 39167. For comparison
purposes, Sargent & Lundy also
performed a sensitivity analysis
showing the values generated by using
the 2001 through 2003 emission rates,
which EPA’s relied upon in making the
BART determination in its proposed
FIP. S&L Evaluation section 6.1.3,
Tables 11–12. The cost effectiveness of
SCR still remains between $5,955 and
$6,298 costs per ton of NOX removed
and incremental cost effectiveness from
SNCR is above $9,000 per ton of NOX
removed. Id. Table 12. These cost
effectiveness values remain prohibitive,
and reinforce Wyoming’s determination
that OFA plus LNB constitutes BART at
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Laramie River and EPA’s 2012 rejection
of SCR as not cost effective.
The Sargent & Lundy Evaluation
further supports Wyoming’s BART
determination for Laramie River Station
by providing a more precise cost
estimate for both SCR and SNCR. At
significant expense, Basin Electric
arranged for an evaluation of the costs
of compliance with SCR and SNCR at a
level of detail that far exceeds what the
CCM requires, but represents the gold
standard for estimating the costs of
compliance for a control technology.
This evaluation demonstrates that the
costs to install SCR at Laramie River
would reach $750 million, far above
what EPA estimates in the proposed SIP
disapproval and FIP. In sum, the
Sargent & Lundy Evaluation supports
Wyoming’s BART determination, and its
decision not to require SCR, with a
detailed consideration of the costs of
compliance for Laramie River.
Moreover, the Evaluation highlights the
fundamental inadequacies in EPA’s own
cost estimates, on which EPA bases both
its decision to disapprove the SIP and
the BART determinations in its FIP.
Response: EPA disagrees with
commenter and has identified numerous
deficiencies in the cost estimate
developed by Sargent & Lundy for the
Laramie River Station that are discussed
in previous responses to comments.
EPA calculated emission reductions
from emission rates indicative of preBART levels in 2001–2003, prior to
addition of combustion controls for
BART. The estimated reduction of NOX
by SNCR and SCR used baseline levels
that were based upon actual emission
rates achieved after the addition of those
combustion controls.
Comment: The EPA’s expert,
Andover, used aerial photographs to
assess the structural and mechanical
changes necessary for installation of the
SCR. As witness Ken Snell
demonstrated at the July 26, 2013,
public hearing, however, an aerial
photograph is wholly inadequate to
assess site-specific conditions that affect
SCR costs. Those relevant site-specific
conditions include, among others, the
following: (1) Site elevation—Laramie
River is situated at 4,750 feet above
mean sea level (MSL), a fact which
affects the flue gas volume which
require a larger SCR reactor, duct work
and structural support; (2) Regional
labor productivity factor—necessary to
account for local workforce
characteristics, labor availability, project
location, project complexity, local
climate and working conditions; (3)
Location of conveyor rooms—aerial
photo cannot reveal conveyor rooms
located in boiler buildings; (4) Location
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of FD Fan buildings—aerial photo
cannot reveal the location of the existing
FD fan buildings; (5) Space
constraints—aerial photo cannot
determine the space constraints between
the FD fan buildings and existing ESPs;
(6) Ammonia handling—aerial photo
cannot provide information about where
the ammonia handling system required
for an SCR could be located, or where
pipe routing could be placed; (7)
Ductwork routing—aerial photo does
not provide information regarding
ductwork routing and SCR tie-ins to the
existing economizers and air heaters;
and (8) Subsystems ignored—aerial
photo does not provide any information
regarding plant subsystems such as ID
fan capacity, equipment reinforcement,
auxiliary power systems, electrical
system capacity, or other plant
subsystems.
Failure to take into consideration the
site-specific, plant-specific
characteristics for installation of SCR
systems necessarily leads to a
significant underestimation of the costs
to install such control technology. EPA’s
expert Andover, using generalized data
and an aerial photograph, estimated the
total capital investment for installation
of an SCR at $330,000,000. However,
when actual site conditions are
considered—i.e. site elevation, regional
productivity factors, site congestion,
balance-of-plant subsystem upgrades
and other indirect costs—expert Ken
Snell estimated the total capital
investment at $746,906,000. Failure of
EPA’s expert to take into consideration
the Laramie River Station’s specific
characteristics and plant configuration
omits approximately $460,000,000 in
very real costs. To turn a blind eye to
site-specific characteristics that have a
major impact on costs of installation
skews the EPA’s cost analysis by more
than 100 percent. Basing the Laramie
River Station BART determination on
EPA’s cost estimates would be arbitrary
and capricious.
EPA proposes to reject Wyoming’s SIP
despite a finding that ‘‘Wyoming
considered all five steps above in its
BART determinations’’ because of
alleged ‘‘flaws and deficiencies’’ in the
cost assumptions and methodology,
including Wyoming’s alleged failure to
‘‘follow the methods set forth in the
EPA Control Cost Manual.’’ 78 FR
34748–34749. To address these alleged
deficiencies, EPA hired its own
consultant, Andover Technology
Partners (‘‘Andover’’), to perform an
independent cost analysis of installing
SNCR and SCR at the Laramie River
Station. Andover, Review of Estimated
Compliance Costs for Wyoming
Electricity Generating Units (EGUs)
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(Oct. 23, 2012), EPA–R08–OAR–2012–
0081 (‘‘Andover Report’’); Andover,
Review of Estimated Compliance Costs
for Wyoming Electricity Generating
Units (EGUs)—revision of previous
memo (Feb. 7, 2013), EPA–R08–OAR–
2012–0086 (‘‘Andover Update’’).
Ironically, it is the cost methodology
relied upon in the Andover Report that
deviates from the BART Guidelines and
the CCM, thereby making Andover’s
analysis inconsistent with EPA’s claim
that cost estimates should not deviate
from the CCM. As a result, EPA’s cost
estimates are less accurate than the
Wyoming cost estimates and the Sargent
& Lundy Evaluation and do not form a
legally supportable basis on which to
base either a SIP disapproval or the
promulgation of a FIP.
Sargent & Lundy, at Basin Electric’s
request, has provided a critique of the
Andover Report that highlights the
numerous technical irregularities in the
cost estimate relied upon by EPA for the
proposed disapproval of the Wyoming
SIP and the FIP. Sargent & Lundy
Laramie River Station Andover Report
Comparison (August 26, 2013), Exhibit
16 (‘‘S&L Critique’’) to commenter 0148.
The Sargent & Lundy Critique
demonstrates that EPA’s reliance on the
Andover Report is not in accordance
with section 169A of the CAA and the
BART Guidelines for three reasons: (1)
Andover relied primarily on the IPM for
cost methodology, which is not
consistent with the BART Guidelines or
the CCM methodology and never was
intended to be used to develop a sitespecific cost estimate. (See section 2.3,
EPA Use of the IPM Cost Models.); (2)
Andover failed to take into account sitespecific conditions and resulting
balance of plant systems required for
SCR and SNCR and therefore did not
comply with the directive in the BART
Guidelines that cost estimates ‘‘take into
account any site-specific design or other
conditions . . .’’ 70 FR 39166.; (3)
Andover ignored NOX reductions
achieved to date by existing control
equipment, thereby artificially
increasing the cost effectiveness of SCR.
If EPA is basing its SIP disapproval on
failure to adhere to the methodology set
forth in the CCM, EPA’s reliance on the
cost estimation in the Andover Report is
wholly inappropriate and imposes an
arbitrary double standard. Not only does
the Andover Report rely on
methodology that deviates from the
CCM, but EPA’s approach is
inconsistent with the requirements of
the BART Guidelines because it does
not adhere to the three-step approach
for cost estimation set forth in the
Guidelines and fails to appropriately
account for ‘‘site-specific design or other
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conditions’’ that ‘‘affect the cost of a
particular BART technology option.’’ 70
FR 39166. Reliance on the Andover
Report for disapproval of the Wyoming
SIP or imposition of a FIP would
constitute arbitrary and capricious
decision making and would run
contrary to the very provisions of law on
which EPA proposes to base its
decision.
Response: EPA disagrees with
commenter and has identified numerous
deficiencies in the cost estimate
developed by Sargent & Lundy for the
Laramie River Station that are discussed
in previous responses to comments.
EPA has also noted in other responses
to comments that, except for elevation,
each of the site-specific issues raised by
commenter has been addressed, or
commenter has not provided adequate
information to support their assertion
that there are unique costs that are not
accounted for in EPA’s cost estimate.
We disagree with the characterization of
the cost development methodology
contained in IPM as inconsistent with
BART guidelines. As noted in the
documentation for IPM’s cost
development methodology for SCR, the
cost estimate methodology is based
upon two databases of actual SCR
projects.226 These databases include
2004 and 2006 industry cost estimates
prepared for the Midwestern Ozone
Group, and a proprietary in-house
database maintained by engineering
firm Sargent & Lundy. The Midwestern
Ozone Group information was crossreferenced with actual 2009 projects,
and as explained elsewhere in this
document, escalated accordingly.
Sargent & Lundy then used the
information in these databases to
develop the equations described in the
cost component taking into account the
pre-control NOX emission level, degree
of reduction, coal type, facility size, and
numerous other unit-specific factors.
While a costly engineering evaluation
that included site visits in addition to
our use of satellite imagery might be
useful, we disagree that our approach is
not sufficiently site specific to satisfy
BART guidelines. As noted by EPA in
previous responses, EPA’s use of
satellite imagery enabled us to evaluate
each of the major site-specific issues.
Comment: EPA argues that ‘‘[w]hen
considering the cost effectiveness and
visibility improvement of new LNBs
plus OFA and SCR, it is within the
range of what EPA has found reasonable
for BART in other SIP and FIP actions.’’
78 FR 34776. EPA’s cost effectiveness
and visibility improvement numbers for
226 https://www.epa.gov/airmarkets/progsregs/epaipm/docs/v410/Appendix52A.pdf.
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Laramie River Station Units 1–3 are
within the range of what EPA has found
not to be reasonable for BART. The case
for rejecting SCR becomes even more
compelling when EPA’s numbers are
corrected to comply with the BART
Guidelines, CCM, and EPA guidance,
and to reflect site specific conditions.
With these comments, Basin Electric is
submitting updated and more accurate
reports with cost estimates and visibility
modeling results based on inputs that
are more correct and consistent with
EPA’s BART Guidelines. Average and
incremental cost effectiveness values for
SCR at Laramie River Station in these
reports are far higher than assumed by
EPA, and visibility improvement
associated with SCR is far lower than
EPA assumed. For EPA to disapprove
the State’s BART determination for
Laramie River Station and proceed with
its FIP in light of this new information
would be egregiously inconsistent with
BART actions it has taken for other
sources.
The following discussion explains
that even with EPA’s cost and visibility
values for Laramie River Station, its
proposed action at Laramie River
Station is inconsistent with actions
elsewhere and EPA should withdraw its
proposed disapproval.
The comparison to Gerald Gentleman
Station (GGS) Units 1–2 is striking. SCR
was rejected at GGS despite
substantially lower costs and very
similar visibility improvement. GGS is a
valid point of comparison despite the
fact that Nebraska adopted the
Transport Rule as a BART alternative.
77 FR 40159. EPA did not make a final
determination as to whether to select
SCR as BART for GGS because Nebraska
became subject to the Transport Rule
and relied on that as a BART alternative.
Id. However, EPA’s proposed rule
discusses the costs and benefits of SCR.
77 FR 12770, 12779 (March 2, 2012). In
its proposed rule, EPA agrees with
Nebraska’s decision to reject SCR at an
average cost effectiveness of $2,297/ton
and an incremental cost effectiveness of
$5,445/ton (both as calculated by
Nebraska). The projections of visibility
improvement were the same in the
proposal and the final rule, i.e. 0.62
delta deciview for each of GGS Units 1
and 2. The proposed rule states that
‘‘EPA agrees that the State’s NOX BART
determination for GGS is reasonable.’’
77 FR 12779. EPA never retracted that
conclusion.
The difference between EPA’s
pending proposals for Wyodak Unit 1
and Laramie River Station Units 1–3 are
equally striking. The average and
incremental cost effectiveness is
virtually the same for these units. So are
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the baseline and incremental visibility
improvement figures. Yet EPA proposes
to require LNB, OFA and SNCR at
Wyodak Unit 1, as opposed to LNB,
OFA and SCR at each Laramie River
Station unit. 78 FR 34785. EPA bases
these differing outcomes on the fact that
SCR at Wyodak Unit 1 would achieve a
cumulative visibility improvement of
1.16 deciviews, whereas SCR at Laramie
River Station Units 1–3 would
reportedly achieve cumulative visibility
improvements of 2.12, 1.97, and 2.29.
Id. Cumulative visibility improvement
at multiple Class I areas is not a valid
criterion for use in BART
determinations. Disregarding the invalid
cumulative criterion, EPA
inconsistently eliminated SCR as BART
at Wyodak based on cost and visibility
values very similar to EPA’s cost and
visibility values for Laramie River
Station.
Also noteworthy is EPA’s decision to
reject SCR as BART at Healy Unit 1
because of its $5,300/ton cost
effectiveness, 0.786 deciview visibility
improvement from the LNB/OFA
baseline, and 0.17 deciview incremental
improvement compared to SNCR. EPA
recalculated the costs after publishing
its proposed rule to account for various
potential useful life scenarios. The
$5,300/ton figure shown here is for a 30
year life. For a 20 year useful life, SCR
would cost $5,900/ton. EPA concluded
that these costs are ‘‘not justified’’ given
the visibility improvement (which was
not recalculated after proposal).
A comparison of the costs and
visibility impacts of installing and
operating SCR at Laramie River Station
Units 1–3 to the costs and visibility
impacts of SCR at the facilities listed
above quickly shows that SCR must be
rejected as BART. EPA has made no
attempt to explain why it proposes to
disapprove the State’s BART for
Laramie River Station and proposes SCR
instead, when it has eliminated SCR at
other facilities based on similar
information. To the extent the
information at the other facilities is a
little different than at Laramie River,
EPA has not and cannot show that the
difference is significant or a reason to
treat the facilities differently.
Response: We disagree with the
commenter’s assertion that our
proposed action for Laramie River
Station, as it relates to the consideration
of SCR as BART, was inconsistent with
our proposed action for other BART
sources in Wyoming or with EPA
actions in other States.
Regarding NOX BART for Gerald
Gentlemen Station in Nebraska, we note
that our proposed approval of the State’s
NOX BART determination, as described
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by the commenter, does not reflect final
agency action. In our final rulemaking
for Nebraska, where the State is subject
to the Transport Rule and FIP for NOX,
we provided the following:
Given the emission reductions provided by
the NOX emission limits associated with
Nebraska’s NOX BART determination of LNB
and OFA for GGS Units 1 and 2, which
strengthen the Nebraska SIP, in conjunction
with the existing Transport Rule FIP which
already applies to Nebraska and has been
determined to provide greater reasonable
progress than BART, in today’s action, EPA
is finalizing its proposed approval of
Nebraska’s SIP as satisfying the requirements
of the Regional Haze Rule with respect to
BART for NOX, and therefore do not inquire
further here as to whether the cost
effectiveness of SCR is low enough and the
associated deciview improvement significant
enough to reasonably determine that SCR is
BART for GGS Units 1 and 2.227
Therefore, because the Transport Rule
removed the need for EPA to consider
SCR for Gerald Gentlemen Station any
further, there is no factual basis to
determine whether our consideration of
SCR in Wyoming differs from that in
Nebraska. In simpler terms, the
commenter has erred by drawing a
comparison with a BART determination
that was never finalized.
We also disagree that our proposed
NOX BART determinations for Laramie
River Station were inconsistent with
that for Healy Unit 1 in Alaska. There,
the cost effectiveness of SCR, using a 20
year lifetime comparable to that used for
Laramie River Station, was found to be
$5,900/ton.228 This cost effectiveness is
greater than that for any of the Wyoming
units for which EPA proposed SCR as
BART, or for which EPA is finalizing
SCR as BART today. The cost
effectiveness of SCR (with combustion
controls) for Laramie River Station units
estimated by EPA in our proposed rule
ranged from $3,589/ton to $3,903/
ton 229—at least 34% less than at Healy
Unit 1. While we have revised these
costs effectiveness estimates for today’s
rule, they remain well below the $5,900/
ton cost effectiveness that EPA
calculated for Healy Unit 1.
Finally, while the costs and visibility
improvement (at one Class I area) for the
Laramie River units and Wyodak
described in our proposed rule may
have been similar, we disagree that the
cumulative visibility benefit was not a
valid criterion for use in BART
determinations. Refer to the modeling
section above where we address our
consideration of cumulative visibility
benefits.
227 77
FR 40159 (emphasis added).
FR 10548.
229 78 FR 34775–34776.
228 78
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We have addressed the updated cost
estimates and visibility modeling
submitted by Basin Electric during the
public comment period in other
response to comments.
Comment: SCR should be rejected for
Laramie River Station Units 1–3 because
of its high cost per deciview of visibility
improvement. EPA did not report the
$/deciview for Laramie River Station,
but dividing the annualized costs by the
visibility improvement (from the preLNB/OFA baseline) reveals that SCR
would cost between $23.0 million and
$27.8 million per deciview of
improvement in the Class I area with the
greatest visibility improvement. These
figures are very similar to the
$/deciview numbers seen at Martin
Drake, Colstrip, Corette, and GGS, and
substantially higher than the $10.8
million and $20 million figures reported
for Lakeland Electric and JEA Northside.
The Laramie River figures are also well
above the $14 million to $18 million per
deciview range that has frequently been
seen as cost effective. EPA has not
considered or justified SCR at Laramie
River in light of its high cost per
deciview.
Not only has EPA proposed to
mandate SCR for Laramie River at
$/deciview levels where SCR has
previously been rejected, EPA has
frequently refused to apply the
$/deciview metric in accordance with
the BART Guidelines. The Guidelines
expressly allow states to evaluate
control technologies based on ‘‘costeffectiveness measures (such as
$/deciview),’’ 70 FR 39170, but EPA has
generally opposed reliance on such a
standard by the states. While
acknowledging that the dollar per
deciview is ‘‘an additional cost
effectiveness metric that can be
employed along with $/ton for use in a
BART evaluation,’’ EPA has not used
$/deciview because it is ‘‘unnecessary,’’
it ‘‘complicates the BART analysis,’’ and
it is ‘‘difficult to judge.’’ 77 FR 57871.
In other rulemakings, EPA has stated
that ‘‘[w]e do not generally recommend
the use of this metric as it can be
complicated to use and the results can
be difficult to assess.’’ 77 FR 76871,
76873 (Dec. 31, 2012). EPA also has
objected to the $/deciview metric
because it claims that metric is based on
the impacts of a single day. 77 FR
57871.
EPA’s reasons for refusing to consider
the $/deciview metric are frivolous.
Even if the $/deciview metric is
complicated or difficult to use, that does
not distinguish it from any other aspect
of the BART determination process.
EPA’s concern that the $/deciview
metric is based on a single day holds no
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water. EPA sometimes bases the
visibility improvement (delta deciview)
of potential control technologies on the
‘‘maximum 98th percentile impact,’’
meaning the 98th percentile day with
the highest deciview improvement
during the relevant period, and
proposes to do so in its analysis of
Laramie River. 78 FR 34775. Indeed, it
is that day’s deciview improvement
which is used to calculate $/deciview.
The $/deciview metric has the virtue of
directly comparing cost to visibility
improvement. It would constrain EPA’s
current use of a nebulous sliding scale
where the agency gives itself the
latitude to point to any one of several
variables as justification for overriding
the State’s choice of BART or for making
its own.
Response: We disagree that our
reasons for not considering the
$/deciview metric are frivolous. We
maintain that, for the reasons discussed
in other regional haze actions, as cited
by the commenter, the $/deciview
metric is problematic and does not offer
any better basis for making BART
determinations than those used by EPA
here—cost effectiveness, incremental
cost effectiveness, and visibility
improvement. Moreover, the BART
Guidelines do not require EPA or the
states to conduct a $/deciview analysis
when evaluating the visibility
improvement factor. Instead, the BART
Guidelines allow flexibility in this area,
stating that: ‘‘You have flexibility to
assess visibility improvements due to
BART controls by one or more methods.
You may consider the frequency,
magnitude, and duration components of
impairment.’’ 70 FR 39170. While the
BART Guidelines suggest cost per
deciview as a possible parameter for
consideration, its use is entirely
discretionary. There are numerous
examples of BART analyses conducted
by states and EPA that have not
calculated this metric.
Comment: The Laramie River Station
began commercial operation in July,
1980, with a permitted limit for NOX
emissions of 0.71 lb/MMBtu. However,
Laramie River was able to significantly
outperform its permitted limits,
achieving an average emission rate that
was much lower, approximately 0.45
lb/MMBtu. In 1996 and 1997, Laramie
River replaced burner nozzles on all
three units and again reduced its NOX
emission rates, to an average of about
0.27 lb/MMBtu. Now, pursuant to
Wyoming’s BART permit, Laramie River
is required to further reduce its NOX
emissions to a limit of 0.21 lb/MMBtu
and 14,474 tons/year in 2014, and
reduce emissions even further by the
end of 2017, to 12,773 tons/year
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(equivalent to 0.158 lb/MMBtu). By
2017, the Wyoming regional haze SIP
will have required the station to reduce
its NOX emission rate by 65% from the
NOX rate emitted when the units were
originally started up. This demonstrates
that the State has achieved very
substantial NOX emission reductions
without undue and wasteful expense.
To put the reductions already
achieved in perspective, the
combination of past reductions and
future required reductions results in
total NOX reductions at Laramie River of
0.29 lb/MMBtu (from 0.45 lb/MMBtu to
0.158 lb/MMBtu). This has been done
and will be done at a significant but
reasonable cost. In contrast, EPA
proposes to require the expenditure of
nearly $750 million dollars to reduce
NOX emissions further, from
0.158 1b/MMBtu to 0.05 lb/MMBtu, a
reduction of only 0.11 lb/MMBtu, less
than half of what has already been
accomplished.
Response: We disagree with this
comment. The RHR and BART
Guidelines instruct states to calculate
the cost-effectiveness and visibility
improvement associated with the
various control options against a
realistic emissions baseline. For the
purposes of BART, most states,
including Wyoming, used a baseline
period of 2000–2004, which
corresponds to the five-year period that
followed the promulgation of the RHR.
Setting a baseline that predates the
promulgation of the RHR, as the
commenter suggests, would be
inappropriate because it would allow
emission reductions that were achieved
as the result of compliance with other
CAA programs to be attributed instead
to BART. Thus, any reductions achieved
at Laramie River between 1980 and 1997
cannot be credited to the source owner,
but must be incorporated into the
baseline, as both the State and EPA
properly did in this case. In regards to
reductions achieved at Laramie River
that have been or will be achieved due
to compliance with the State’s BART
determination, these reductions will
also occur under EPA’s FIP.
Consequently, a more accurate way of
comparing the State’s regional haze SIP
to EPA’s FIP is to subtract the ultimate
emission rate achieved by each plan
from the baseline. Using the
commenter’s emission rates, the State’s
regional haze SIP would reduce
emissions at Laramie River by 0.112
lb/MMbtu from the baseline, while
EPA’s FIP will reduce emissions by 0.22
lb/MMbtu. For a more detailed
discussion of baseline emissions and the
flaws in the commenters’ logic, see our
response to similar comments on the
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consideration of existing controls in use
at a source.
Comment: The costs of installation of
the SCRs at Laramie River Station
impose an economic impact that is
unjustified by the facts of this case. The
regulation of regional haze is focused on
improving visibility, not public health.
Yet, the improvement in visibility that
EPA suggests will be created by
installation of SCRs, as opposed to the
Wyoming SIP’s LNBs/OFA, does not
carry with it a significant improvement
in visibility. By EPA’s own calculations,
installation of SCRs will result in only
a 0.79 deciview visibility improvement
at the most impacted Class I area,
Badlands National Park, and those
calculations substantially overstate the
visibility improvement that would
actually be achieved. By its very
definition, this small incremental
improvement in visibility is not even
perceptible by the human eye.
Response: We disagree with this
comment. As stated in section IV.C.5
above, even though the visibility
improvement from an individual source
may not be perceptible, it should still be
considered in setting BART because the
contribution to haze may be significant
relative to other source contributions in
the Class I area. Thus, we disagree that
the degree of improvement should be
contingent upon perceptibility. Failing
to consider less-than-perceptible
contributions to visibility impairment
would ignore the CAA’s intent to have
BART requirements apply to sources
that contribute to, as well as cause, such
impairment.230
Comment: EPA asserts that
Wyoming’s alleged ‘‘deviations’’ from
the BART Guidelines and CCM form
adequate grounds for rejection of its
SIP—yet the BART determinations
included in EPA’s proposed FIP eschew
the very standards to which it holds the
State. EPA’s estimate of the ‘‘cost of
compliance’’ for installation of SCR and
SNCR at Laramie River Station is
grounded in an outside consultant’s
report that expressly dismisses the
recommendations of EPA’s own CCM in
favor of a methodology that is
inconsistent with the directives of the
BART Guidelines and fails to account
230 The preamble to the BART Guidelines state,
‘‘[e]ven though the visibility improvement from an
individual source may not be perceptible, it should
still be considered in setting BART because the
contribution to haze may be significant relative to
other source contributions in the Class I area. Thus,
we disagree that the degree of improvement should
be contingent upon perceptibility. Failing to
consider less-than-perceptible contributions to
visibility impairment would ignore the CAA’s
intent to have BART requirements apply to sources
that contribute to, as well as cause, such
impairment’’ (70 FR 39104, 39129, July 6, 2005).
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for critical site-specific factors that
affect the cost of these technologies at
Laramie River. The resulting cost
estimates are not representative of the
costs that Basin Electric would incur for
the installation of SCR and SNCR and
do not form a legally supportable basis
on which to promulgate a FIP. To
finalize a FIP based on the cost
effectiveness estimates in the Andover
Report would constitute arbitrary and
capricious decision making and would
run contrary to the same provisions of
law on which EPA bases its disapproval
of Wyoming’s SIP.
The Andover Report uses a high-level
model that was never intended to be
used to estimate site-specific costs. But
neither Andover nor EPA offers any
explanation of why reliance on the IPM
model is more appropriate than either
the CCM recommendations or a sitespecific scoping level study such as the
Sargent & Lundy Evaluation. Indeed,
EPA’s preamble notes that the cost
estimate relied primarily on the IPM
model, but then simply parrots the
conclusions of the Andover Report
without further analysis or discussion.
Although EPA has the discretion to rely
on a model of its choice, EPA’s reliance
on the IPM model to estimate costs
requires both an explanation of the
assumptions made and a defense of this
particular methodology—particularly
because EPA has proposed disapproval
of Wyoming’s SIP for failure to adhere
strictly to the CCM methodology. See
Appalachian Power, 249 F.3d at 1053.
EPA has failed to ‘‘make plain its course
of inquiry, its analysis and its
reasoning’’ and therefore promulgation
of a FIP based on the Andover Report
would be arbitrary and capricious.
Olenhouse, 42 F.3d at 1575.
EPA’s BART determinations relied
upon methodology that does not comply
with the BART Guidelines. Specifically,
Andover did not adhere to the threestep process in the BART Guidelines for
estimating the ‘‘costs of compliance’’
because the analysis set forth in the
report did not adequately define the
emission units being controlled, failed
to identify site-specific design
parameters that affect cost and
performance of the controls, and used
the IPM model to develop cost estimates
that are neither technically defensible
nor representative of the costs of SCR
and SNCR systems at Laramie River.
First, Andover’s use of the IPM
model—which requires only four
inputs—is so general that it failed to
adequately define the operating
parameters of Laramie River Station
Units 1 through 3. Second, both the IPM
model and Andover’s manipulation of
the cost algorithms ignored numerous
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site-specific variables that would have a
substantial effect on the costs incurred
by Basin Electric. These variables
include, among other items, failure to
account for the elevation of Laramie
River and the complexities of SCR at the
facility. Finally, Andover used out-ofdate and inaccurate emissions from
Laramie River Units 1 through 3 on
which to base its cost effectiveness
analysis. These emissions estimates did
not take into consideration the
reductions that result from the
installation of OFA and LNB at these
units, which have reduced the baseline
NOX emissions to 0.19 lb/MMBtu. As a
result of these inadequacies, the
Andover Report makes inaccurate cost
estimates that are not representative of
the costs that Basin Electric would incur
for installation of either SNCR or SCR.
By relying on the Andover Report, EPA
has ‘‘complete[ly] failed to consider the
criteria that should inform’’ its BART
determination, and a court would
accord EPA’s BART determination no
deference and would determine that it
is arbitrary, capricious, an abuse of
discretion and not in accordance with
the law. Nat. Resources Defense
Council, 725 F.2d at 771; see also
Appalachian Power, 249 F.3d at 1052;
Sierra Club v. Costle, 657 F.3d at 333.
Response: Each of the commenter’s
claims have been addressed above in
other responses and elsewhere in this
document. In these responses we have
substantiated that the cost methodology
employed by EPA, including use of the
IPM-based cost algorithms, is consistent
with the BART Guidelines and CCM.
Moreover, we modified our cost
estimates in response to site-specific
information provided by Basin Electric
during the comment period. Therefore,
we reject the commenter’s assertions
that (1) we have dismissed the
recommendations of the CCM in favor of
a methodology that is inconsistent with
the directives of the BART Guidelines,
and (2) failed to account for critical sitespecific factors.
We have addressed the commenter’s
concern regarding whether our costeffectiveness analysis reflects the
relatively lower emissions achieved
with recent combustion control updates
(OFA and LNB) in section V.A.12 above.
Comment: Wyoming concluded that
SCR would lower the NOX emission rate
of Laramie River Units 1–3 to 0.07 lbs/
MBtu on a 30-day rolling average basis
and used the 0.07 lbs/MMBtu controlled
NOX rate to estimate costs. 78 FR 34748;
WDEQ Revised NOX BART Impact
Analysis AP–6047A (January 3, 2011)
(‘‘2011 Revised BART Analysis’’) at 3,
Table 2–2, docket cite EPAR08–OAR–
2012–0026–0003.
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The State’s administrative record
supports its selection of 0.07 lb/MMbtu
on a 30-day rolling average as an
appropriate post-SCR NOX emissions
rate. Wyoming first presented this
emissions rate in its BART Application
Analysis AP–6047. Wyoming BART
Analysis at 8, Table 2. Wyoming
explained its rationale in its December
31, 2009 response to comments on
BART Permit AP–6047. Available at
EPA–R08–OAR–2012–0026–0058,
Exh. 3.
Wyoming then provided a table
comparing SCR control efficiencies at
seven similar coal fired EGUs. The NOX
emission rate selected by Wyoming is
squarely within the range of control
efficiencies identified by the State’s
search. Of note are the NOX emission
rates for the Iatan Station (0.08 lb/
MMbtu, 30-day average), Big Cajun II
Power Plant (0.07 lb/MMBtu annual
average), and OPPD—Nebraska City
Station (0.07 lb/MMbtu, 30-day
average). Id. Wyoming’s explanation
and supporting data negate any
contention that the State violated the
CAA or acted unreasonably when it
chose to evaluate SCR using a NOX
control efficiency of 0.07 lb/MMbtu on
a 30-day rolling average basis.
EPA contends that whereas Wyoming
assumed that adding SCR controls at
Laramie River would achieve a control
effectiveness of 0.07 lb/MMBtu, ‘‘EPA
has determined that on an annual basis
SCR can achieve emission rates of 0.05
lb/MMBtu or lower.’’ 78 FR 34748. EPA
provides no explanation and cites
nothing to support how it ‘‘determined’’
this to be the case. It doesn’t associate
the 0.05 lb/MMBtu with any specific
facility or unit—it just makes this
blanket assertion.
Nor can EPA assert that Wyoming’s
0.07 lb/MMBtu assumed control level
conflicts with the CAA or the BART
Guidelines. Nothing in the Guidelines
dictates what SCR can achieve, and EPA
cites no provision of the Guidelines to
support its claim. In fact, EPA’s blanket
claim that 0.05 lb/MMBtu must always
be used itself conflicts with the
Guidelines, which make clear that
BART is a site-specific determination,
not a blanket finding. The notion that
EPA can apply an across-the-board
value and thereby deprive the State of
its ability to exercise discretion on an
individual case basis is contrary to the
holding in American Corn Growers, 291
F.3d at 7–10.
The lack of support for EPA’s claim
that the 0.07 lb/MMBtu is a ‘‘flaw’’ is
reinforced by EPA’s own acceptance of
this value in BART analyses by other
States. For example, in Colorado,
commenters on EPA’s proposed
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approval of the State’s regional haze
SIP, including BART determinations,
argued that the State was wrong in
assuming that at Tri-State’s Craig
Station Units 1 and 2, SCR would
achieve only a 0.07 lb/MMBtu NOX
emission rate on an annual basis;
however, EPA did not disapprove
Colorado’s BART determinations for
this reason or find that this was an error.
EPA’s response to the comments stated
that it agreed that ‘‘SCR in some cases
can achieve annual NOX emission rates
as low as 0.05 lb/MMBtu’’ but that the
‘‘annual emission rate assumed by
Colorado, 0.07 lb/MMBtu, is within the
range of actual emission rates
demonstrated at similar facilities in
EPA’s Clean Air Markets Division
(CAMD) emission database.’’ 77 FR
76871, 76873. Similarly, although
commenters argued that SCR at Alaska’s
Healy Unit 1 could achieve a NOX
emission rate of 0.035 lb/MMBtu, EPA
evaluated using a rate of 0.07 lb/MMBtu
to evaluate SCR. 78 FR 10546, 10548.
EPA evaluated SCR using an emission
rate of 0.06 lb/MMBtu for Nevada’s Reid
Gardner Generating Station. 77 FR
21896, 21903 (calling this a ‘‘mid-range
option’’).
Also, EPA accepted an even higher
post-SCR NOX emission rate of 0.10 lb/
MMBtu for Jeffrey Energy Center Units
1 and 2. Kansas SIP Approval, 76 FR
80754, 80756. This emission rate was
‘‘within the range of effectiveness that
the State believed to be reasonable as a
retrofit control on older tangential-fired
units.’’ Id. EPA deferred to Kansas,
noting that ‘‘EPA believes the State’s
decision to choose a control efficiency
within the middle of the range for the
purpose of estimating cost is a
reasonable approach and is acceptable
according to the BART Guidelines.’’ Id.
If it was not error and not unreasonable
or arbitrary for Colorado and Kansas to
use 0.07 or 0.10 lb/MMBtu, it cannot be
error, or unreasonable, or arbitrary, for
Wyoming to use the same or lower
value.
Response: We have addressed the
control effectiveness of SCR above in
section V.C.3 above. Again, we agree
that it was appropriate for Wyoming to
set the 30-day rolling average emission
limit for SCR installations at 0.07 lb/
MMBtu. And again, EPA’s use of an
actual annual emission rate of 0.05 lb/
MMBtu for cost calculation purposes is
supported by information supplied by
control equipment consultants or
vendors and submitted along with
comments from PacifiCorp and Basin
Electric.
We also note that the commenter has
compared the 30-day allowable rates
established at certain facilities to the
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annual emission rate used by EPA to
calculate cost effectiveness. These
values are not directly comparable. This
is because: (1) The former is on a 30-day
basis, while the latter is on an annual
basis, and (2) the former is an allowable
emission limit, while the latter is an
actual emission rate.
The remaining comments have been
addressed elsewhere in this document.
Comment: For the same reasons that
SNCR is not a relevant basis for
disapproving Wyoming’s BART for
Laramie River Station, the price of urea
is likewise not relevant. The price of
urea relates only to SNCR technology,
not to SCR. As noted above, SNCR is not
a relevant factor to support EPA’s
rejection of the State’s NOX BART for
Laramie River Station because neither
the State’s SIP nor EPA’s proposed FIP
chooses SNCR as BART. SNCR has been
taken off the table by EPA, so the
attempt to base its BART disapproval on
SNCR issues is specious. EPA cannot
reasonably base its disapproval on the
State’s alleged failure to properly
consider the cost of a technology that
EPA itself rejects.
Response: We disagree. The BART
selection process requires a comparison
between all technically feasible control
options, not the evaluation of individual
control technologies in isolation. While
the BART Guidelines do not specify the
order in which control options must be
evaluated (e.g., beginning with the most
stringent or beginning with least
stringent control), they do specify that
the CAA factors must be considered for
all options: ‘‘In the final guidelines, we
have decided that States should retain
the discretion to evaluate control
options in whatever order they choose,
so long as the State explains its analysis
of the CAA factors.’’ 70 FR 39130. The
only exceptions are ‘‘. . . if you find
that a BART source has controls already
in place which are the most stringent
controls available . . .’’, or ‘‘. . . . if a
source commits to a BART
determination that consists of the most
stringent controls available . . .’’ 70 FR
39165. In these situations, it is not
necessary to complete an analysis of all
five BART factors. Therefore, because
neither of these criteria was met, the
State was required to perform an
analysis of all five BART factors for all
technically feasible control options.
And if, as EPA has established in other
responses, the analysis of one of those
options, such as SNCR, was flawed,
then the State could not sensibly
identify the best available option among
all of the control options considered.
Therefore, regardless of whether the
State or Wyoming rejected SNCR as
BART, it is mistaken for the commenter
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to suggest that the analysis of SNCR was
somehow immaterial in the selection of
BART.
It is particularly important that the
costs of SNCR be properly estimated in
relation to the calculation of
incremental cost effectiveness. (The
incremental cost of effectiveness should
be calculated in addition to the average
cost effectiveness. 70 FR 39167). The
cost of SNCR affects the incremental
cost effectiveness between SCR and
SNCR, as well as incremental cost
effectiveness between SNCR and
combustion controls. If the cost of SNCR
is incorrect, the incremental cost
effectiveness between control options
will also be incorrect. This underscores
the point that, if the underlying
assumptions were flawed, the State
could not have reasonably chosen
between competing control options.
We have addressed the price of urea
in a separate response.
Comment: EPA is proposing that the
FIP NOX BART emission limit for Basin
Electric Laramie River Unit 1, Unit 2,
and Unit 3 is 0.07 lb/MMBtu (30-day
rolling average). While we are generally
pleased with EPA’s proposal, we note
that EPA’s analysis is based on only
74% NOX control by the SCRs, and still
results in each EGU contributing 0.5
deciview to visibility impairment at
Badlands National Park.
Based on an evaluation of the rolling
30-boiler operating day average NOX
emission rates from Laramie River Units
1–3 with emissions data available in
EPA’s CAMD database, a NOX limit of
0.07 lb/MMBtu on a rolling 30-boiler
operating day basis would only require
Laramie River Units 1–3 to achieve
61–70 percent NOX removal across the
SCR systems. A 0.05 lb/MMBtu NOX
emission limit applicable on a rolling
30-boiler operating day average basis
would only require 73–79 percent NOX
removal across the SCR, which is
readily achievable.
Response: We have addressed the
control effectiveness of SCR above in
section V.C.3 above.
Comment: Moreover, the Sargent &
Lundy evaluation demonstrates, based
on a detailed scoping-level cost
analysis, that SCR will cost
approximately $9,000 per ton of NOX
removed, further demonstrating the
arbitrariness of EPA’s proposed
disapproval of the State’s NOX BART
determination for Laramie River Station.
Sargent & Lundy Evaluation, Table 7.
Response: We disagree that SCR will
cost $9,000/ton as indicated by the
commenter. We have incorporated
certain costs claimed by Sargent &
Lundy in their evaluation, but not
others. We have addressed the Sargent
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& Lundy cost analysis, including our
rationale for not accepting certain costs,
in detail in other responses. Our revised
cost analysis of SCR plus combustion
controls, indicates that the cost
effectiveness for the three units is
between $4,375/ton and $4,461/ton.
Comment: EPA should have used 30day average emission limits in the cost
effectiveness analysis, rather than
expected/actual emission rates, to be
consistent with how EPA and states
have done other BART cost
effectiveness calculations.
Response: We disagree. As we have
stated in other responses, our use of the
anticipated actual annual emission rate
is consistent with the BART Guidelines.
As we previously noted, cost
effectiveness is more appropriately
based on the reduction in annual
emissions, not the change in allowable
emissions.
Comment: We received a comment
that EPA’s consultant did not take into
account site-specific data for Laramie
River Station.
Response: We have addressed this
issue in a separate response. As noted
there, we have incorporated many of the
costs suggested by Basin Electric’s
consultant, Sargent and Lundy, in our
revised costs supporting this final
action.
Comment: Wyoming has
underestimated the cost of SNCR.
Wyoming estimated LNB+OFA+SNCR
would cost $2,056–$2,109/ton. EPA
calculated the incremental costs of SCR
versus LNB+OFA+SNCR, its preferred
control option, and estimated
incremental costs of $7,054–$7,242/ton.
We are concerned that Wyoming
underestimated the cost of SNCR, which
biases its emphasis on incremental costs
against SCR. We calculated the costs of
SNCR using the CCM (with the reagent
correction used by EPA for Montana),
and heat inputs and emission estimates
from CAMD data for 2001–2003. Based
upon application of the CCM, we
estimate SNCR cost-effectiveness at
$2,358–$2,536/ton, which is $300–
$400/ton higher than Wyoming’s
estimates.
Response: We agree that Wyoming has
underestimated the cost of SNCR for the
Laramie River Station units. In order to
address deficiencies in Wyoming’s
SNCR cost estimates for the Laramie
River Station units identified by
commenters, such as the control
effectiveness of SNCR, we have
conducted a revised cost analysis.
Comment: Wyoming has
underestimated the ability of SCR to
reduce emissions. In estimating the
annual cost-effectiveness of the
LNB+OFA+SCR option, Wyoming
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assumed 0.07 lb/MMBtu, which
represents 74% control efficiency on an
annual average basis, as opposed to the
generally-accepted 90%. Wyoming has
not provided any documentation or
justification to support the higher
emission rates used in its analyses. In
other recent BART actions, EPA has
determined that SCR can achieve 0.05
lb/MMBtu on an annual basis. Such an
underestimate at Laramie River Station
biases the cost-benefit analysis against
SCR and is inconsistent with other EPA
analyses.
Response: The commenter has
incorrectly assumed that a 90% control
efficiency can be achieved in all SCR
applications regardless of the input NOX
emission rate or other parameters. In
addition, we note that the emission rate
analyzed by Wyoming, 0.07 lb/MMBtu,
was on a 30-day rolling average basis,
not an annual basis. Regardless, we
agree that SCR can in most cases
achieve a performance rate of 0.05 lb/
MMBtu on an annual basis. (See the
section IV.C.4 of this document for more
information regarding the control
effectiveness of SCR). We have revised
the SCR costs for the Laramie River
Station units accordingly.
Comment: The final state BART
determination sets NOX emission limits
of 0.21 lb/MMBtu, 30-day average, and
related lb/hour and tons/year limits.
However, EPA does not analyze these
limits and find they are unreasonable. It
analyzes instead a NOX emission limit
of 0.23 lb/MMBtu, which is not the
actual final BART limit but rather an
initial limit in the BART permit that
was appealed and was changed in the
settlement of that appeal and
incorporated in the final SIP. Therefore,
EPA’s disapproval pertains to a BART
limit that is different than the actual
BART limit. Using the wrong BART
limit is arbitrary and unreasonable.
Response: In our revised cost and
visibility analyses for the Laramie River
Station BART units, we have addressed
the issue described by the commenter.
However, we have not analyzed the 0.21
lb/MMBtu limit directly as it is assessed
on a 30-day rolling average basis.
Instead, as described above, we have
used the actual annual emission rate of
0.19 lb/MMBtu demonstrated since the
installation of new LNBs and OFA. Our
approach is consistent with the BART
Guidelines which state: ‘‘. . . you will
estimate the anticipated annual
emissions based upon actual emissions
from a baseline period.’’ 70 FR 39167.
Comment: The purpose of the regional
haze program is to improve visibility in
Class I areas. The amount of emission
reductions by itself, without any
connection to visibility improvement, is
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irrelevant because without some
connection to visibility improvement
we cannot judge the significance of such
reductions in light of the ‘‘overarching
purpose of the regional haze program’’
to protect visibility in Class I areas.
Since EPA acknowledges that SNCR
would not improve visibility by a
perceptible amount, the amount of NOX
emission reductions standing alone does
not further the purpose of the program.
Response: We disagree that the
visibility improvements for Laramie
River Station are de minimis or too
small to justify the expense of requiring
controls. The BART Guidelines are clear
that it is not necessary for the visibility
improvement of a particular control
option to be above the perceptible
threshold: ‘‘Even though the visibility
improvement from an individual source
may not be perceptible, it should still be
considered in setting BART because the
contribution to haze may be significant
relative to other source contributions in
the Class I area. Thus, we disagree that
the degree of improvement should be
contingent upon perceptibility. Failing
to consider less-than-perceptible
contributions to visibility impairment
would ignore the CAA’s intent to have
BART requirements apply to sources
that contribute to, as well as cause, such
impairment.’’ 70 FR 39129.
EPA followed the BART Guidelines in
determining what BART was for each
unit, taking into account the five factors,
including visibility improvement and
the cost effectiveness of controls (which
includes an assessment of the dollars
per ton removed).
2. Jim Bridger Units 1–4
a. NOX BART Determination
Comment: In estimating the annual
cost-effectiveness of the LNB/
SOFA+SCR option, Wyoming assumed
0.07 lb/MMBtu on an annual average
basis. Based on the 0.026 lb/MMBtu
NOX emission rate predicted for the
LNB/SOFA option, and the 0.20 lb/
MMBtu annual emission rates
demonstrated by all four Bridger units,
outlet emissions at 0.07 lb/MMBtu
represent only a 65%–73% SCR control
efficiency as opposed to the generallyaccepted 90%. Wyoming has not
provided any documentation or
justification to support the higher
emission rates used in its analyses. In
other recent BART actions, EPA has
determined that SCR can achieve 0.05
lb/MMBtu on an annual basis. Such an
underestimate at Bridger biases the costbenefit analysis against SCR and is
inconsistent with other EPA analyses.
Response: The commenter has
incorrectly assumed that a 90% control
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efficiency can be achieved in all SCR
applications regardless of the input NOX
emission rate or other parameters. In
addition, we note that the emission rate
analyzed by Wyoming, 0.07 lb/MMBtu,
was on a 30-day rolling average basis,
not an annual basis. Nonetheless, we
agree that SCR can, in most cases,
achieve a performance rate of 0.05 lb/
MMBtu on an annual basis.
Comment: Based on an evaluation of
the rolling 30-boiler operating day
average NOX emission rates from Jim
Bridger Units 1–4 over the period of
January 1, 2011 through March 31, 2013
with emissions data available in EPA’s
CAMD, a NOX limit of 0.07 lb/MMBtu
on a rolling 30-boiler operating day
basis would only require Jim Bridger
Units 1–4 to achieve 66–68 percent NOX
removal across the SCR systems. The
commenter asserted that a 0.05 lb/
MMBtu NOX emission limit applicable
on a rolling 30-boiler operating day
average basis would only require 75–77
percent NOX removal across the SCR,
which the commenter believes is readily
achievable. (The commenter’s
arguments regarding the achievable
level of NOX control with SCR are
summarized elsewhere in this
document.)
Response: We have addressed the
control effectiveness of SCR above in
section V.C.3 above.
Comment: EPA’s reliance on selected
‘‘affordability’’ language in its BART
Guidelines does not support EPA’s
decision to exempt all Jim Bridger from
SCR BART requirements. First, Congress
established five factors—no more—that
EPA must consider when making
source-by-source BART determinations.
42 U.S.C. 7491(g). Applying those five
factors alone, EPA determined that SCR
was BART for all four Bridger Units. 78
FR 34756. By considering the
‘‘affordability’’ of BART controls across
PacifiCorp’s entire fleet, EPA has
arbitrarily relied on factors which
Congress has not intended it to
consider. Motor Vehicle Mfrs. Ass’n v.
State Farm Mut. Auto. Ins. Co., 463 U.S.
29, 43 (1983f); Pac. Coast Fed’n of
Fishermen’s Ass’ns, Inc. v. Nat’l Marine
Fisheries Serv., 265 F.3d 1028, 1034 (9th
Cir. 2001); see also North Carolina v.
Envtl. Prot. Agency, 531F.3d 896, 906
(D.C. Cir. 2008) (standard of review is
the same under the APA and the CAA,
42 U.S.C. 7607).
Response: We disagree with the
commenter that when considering the
five factors alone, SCR is BART on all
the Jim Bridger units. As discussed in
section III.B.6 above, when considering
the five factors, we find it unreasonable
to require SCR as BART on these two
units and instead we are approving the
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State’s LTS for (all four or Units 1 and
2) the Jim Bridger units. We are not
relying on the affordability analysis in
making this final determination.
Comment: 40 CFR part 51, Appendix
Y, section IV.E.3 makes clear that the
affordability analysis should be limited
to the economic impact of the BART
unit at issue—not to a utility’s fleetwide BART obligations as a whole.
EPA’s application of this language to
PacifiCorp’s BART obligations at other
power plants is improper. In addition,
the BART Guidelines establish a very
narrow test for applying the
affordability language, which is whether
requiring installation of the control
technology would ‘‘have a severe impact
on plant operations.’’ 40 CFR part 51,
app. Y, section IV.E.3. In such
circumstances, the BART Guidelines
suggest that EPA prepare ‘‘an economic
analysis that demonstrates, in sufficient
detail for public review, the specific
economic effects, parameters, and
reasoning.’’ EPA has not prepared an
economic analysis demonstrating the
specific economic, parameters, and
reasoning for its decision to exempt the
Jim Bridger facility from further BART
controls. Instead, EPA simply concludes
that ‘‘it would be unreasonable to
require any further retrofits at this
source within five years of our final
action’’ based on PacifiCorp’s BART
obligations at other facilities. 78 FR
34756. Further, PacifiCorp has not
presented evidence that installation of
SCR at each Bridger unit within the first
regional haze planning period would
cause any noticeable economic impact,
let alone ‘‘severe’’ impact, such a
shutdown of one or all of the units.
Response: As discussed in more detail
in a response to another comment
below, we agree that PacifiCorp has not
provided sufficient evidence to show
that the installation of SCR at the Jim
Bridger units within five years after our
final action would cause a severe
economic impact. We are basing our
decision to not require SCR for BART
based on our weighing of the five
factors.
Comment: The BART Guidelines also
suggest that if the agency grants an
affordability exemption from the best
level of control, it must then select a
‘‘slightly lesser degree of control.’’ 40
CFR part 51, app. Y, section IV.E.3.
EPA’s proposal does not require any
additional level of control under BART.
Instead, EPA’s 2013 re-proposal selects
the pre-existing LNB/OFA as BART for
each unit. EPA’s choice of LNB/OFA as
BART does not even represent the
‘‘second best’’ control technology for
eliminating NOX related visibility
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5183
impairment—which would be SNCR. 78
FR 34756 (Table 13).
Response: As stated above, we are not
basing our BART determination for Jim
Bridger Units 1 and 2 on an affordability
argument.
Comment: The BART Guidelines
‘‘affordability’’ language recommends
that states (or EPA) consider ‘‘whether
other competing plants in the same
industry have been required to install
BART controls if this information is
available.’’ 40 CFR part 51, app. Y,
section IV.E.3. This provision suggests
that SCR requirements should be
applied consistently among competing
utility companies. EPA’s exemption of
PacifiCorp from SCR obligations at the
Jim Bridger units is inconsistent with its
actions at other competing utility
companies with large coal fleets, to
which EPA has not offered
‘‘affordability’’ exemptions from SCR
requirements. For example, EPA has
required Salt River Project, a competing
utility, to install SCR on numerous coalplant units in its fleet, including
Coronado and Navajo (Arizona), Craig
and Hayden (Colorado) and Four
Corners (New Mexico). Each of EPA’s
BART determinations for these plants
requires installation of SCR as BART
within the mandated five-year
implementation deadline.
EPA’s 2013 re-proposal for Jim
Bridger exempts the plant from both the
SCR requirement and the five-year
implementation deadline, potentially
giving PacifiCorp an advantage over the
competing utilities. Thus, EPA’s 2013
re-proposal rule is not only inconsistent
with its own BART Guidelines, it is
competitively unfair.
Response: We agree that other utility
companies have had to install SCR
within the five year BART window and
that evidence provided by PacifiCorp
does not support delaying controls on
Jim Bridger Units 1 and 2 until 2022 and
2021, respectively. Nonetheless, as
stated earlier, we are no longer basing
our BART determination for Jim Bridger
Units 1 and 2 on an affordability
argument.
Comment: We are very familiar with
the ‘‘affordability’’ provisions of the
BART Guidelines and have dealt with
this issue in Arizona (Apache power
plant) and Washington (Alcoa’s Intalco
primary aluminum smelter). In both of
those cases, the company requesting the
affordability exemption from BART
provided extensive documentation
(much of it confidential) to EPA and the
FLMs to support its request. It was only
after a thorough review by EPA that the
affordability exemptions were approved.
In this case, it appears that the only
information presented by PacifiCorp to
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support its request is its ‘‘assertions’’
dated July 12, 2012. We believe that a
more rigorous analysis is necessary in
order for EPA, FLMs, and the public to
be assured that the additional time
being proposed by EPA is necessary and
appropriate. For example, an important
part of such an analysis would be the
‘‘installation schedule’’ that PacifiCorp
has designed in order to minimize the
number of units that are out of service
system-wide for installation of
emissions controls at any one time.
Currently, the only schedule available
in the docket is the July 2012 letter from
PacifiCorp to EPA in which PacifiCorp
simply reiterates the dates proposed for
its ‘‘Installation Requirements.’’
Response: As stated in other
responses to comments, we agree that
the information provided by PacifiCorp
was not sufficient to support the delay
of SCR controls on Jim Bridger Units 1
and 2, but we are not relying on that
information in our BART determination.
Comment: EPA’s proposal for Jim
Bridger Units 1 and 2 is a ‘‘do nothing’’
BART determination. Although the
Agency claims that it is proposing to
approve the State’s proposal to require
the use of LNBs for Units 1 and 2 and
for both units to meet an emission rate
of 0.28 lb/MMBtu over a 30-day rolling
period, this emission rate is actually
higher than what Units 1 and 2 are
currently emitting and worse, does not
reflect the presumptive BART limits set
forth in 40 CFR part 51, Appendix Y.
Most significantly, it defies the statutory
intent of Congress in establishing the
regional haze program under the CAA.
According to EPA’s CAMD Web site,
both Units 1 and 2 already consistently
achieve 30-day rolling average NOX
emissions lower than 0.20 lb/MMBtu.
The data illustrates that Jim Bridger
Units 1 and 2 consistently achieve NOX
emission rates below 0.20 lb/MMBtu on
a monthly basis and have done so since
2010. To this end, the definition of
BART explicitly states that it must
represent a ‘‘reduction’’ in each
pollutant that causes or contributes to
visibility impairment. See 40 CFR
51.301 (setting forth definition of
BART).
Furthermore, although a state must
take into account the five factors set
forth under 42 U.S.C. 7491(g)(2),
nothing in the CAA or the EPA’s
regulations implementing the regional
haze program suggest or remotely imply
that a state could allow emission
increases as BART. Accordingly, EPA
must, at a minimum, disapprove of
Wyoming’s NOX BART determinations
for Jim Bridger Units 1 and 2 and adopt
a FIP that establishes BART limits that
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are consistent with the CAA and that
represent actual emission reductions.
Response: We disagree with the
commenter that BART is an emission
limit of 0.07 lb/MMBtu at Jim Bridger
Units 1 and 2 within five years of our
final action. As discussed previously,
based on our weighing of the five
factors, we do not find it reasonable to
require SCR for BART on Jim Bridger
Units 1 and 2 and instead we are
approving the State’s LTS for these
units.
Comment: The need to promulgate a
FIP is underscored by the EPA’s own
BART guidelines. According to those
guidelines, tangentially fired boilers
burning subbituminous coal, such as
Jim Bridger Units 1 and 2, are presumed
to be able to cost-effectively meet a NOX
emission rate of 0.15 lb/MMBtu on a 30day rolling average basis. See 40 CFR
part 51, Appendix Y, Table 1. EPA’s
claim that it would not be cost-effective
to meet an emission rate below 0.28 lb/
MMBtu as BART for Units 1 and 2 is
therefore undercut by the Agency’s own
extensive analysis and conclusion that a
0.15 lb/MMBtu rate is presumed to be
appropriate. Tellingly, the EPA nowhere
in its proposed rule analyzes or
addresses why a 0.28 lb/MMBtu rate is
appropriate in light of the Agency’s own
presumptive BART limits for NOX
emissions from tangentially-fired boilers
burning subbituminous coal.
Response: We disagree with the
commenter’s assertion that our approval
of non-presumptive BART emission
limits for Jim Bridger Units 1 and 2 is
flawed. In the BART Guidelines EPA
explained that:
For coal-fired EGUs greater than 200 MW
located at greater than 750 MW power plants
and operating without post-combustion
controls (i.e. SCR or SNCR), we have
provided presumptive NOX limits,
differentiated by boiler design and type of
coal burned. You may determine that an
alternative control level is appropriate based
on a careful consideration of the statutory
factors. For coal-fired EGUs greater than 200
MW located at power plants 750 MW or less
in size and operating without postcombustion controls, you should likewise
presume that these same levels are costeffective. You should require such utility
boilers to meet the following NOX emission
limits, unless you determine that an
alternative control level is justified based on
consideration of the statutory factors.231
Therefore, the presumptive emission
limits in the BART Guidelines are
rebuttable, and the five statutory factors
enumerated in the BART Guidelines
provide the mechanism for establishing
different requirements. Specifically, as
231 40
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explained in the preamble to the BART
Guidelines:
If, upon examination of an individual EGU,
a State determines that a different emission
limit is appropriate based upon its analysis
of the five factors, then the State may apply
a more or less stringent limit.232
Thus, the establishment of
presumptive BART emission limits does
not preclude states or EPA from setting
limits that differ from those
presumptions, even where the control
technology is the same as that
associated with the presumptive limits
(in this case, combustion controls). The
five-factor analysis performed by
Wyoming demonstrates that, because of
the nature of the coal fired at these
units, the presumptive limit of 0.15 lb/
MMBtu is not attainable. Wyoming
supported this conclusion with
information from an established vendor
of combustion controls.233 We concur
with those conclusions and find that
Wyoming’s BART emission limits for
Jim Bridger Units 1 and 2 were
established in a manner consistent with
the BART Guidelines.
Comment: EPA’s proposal is
fundamentally flawed because it makes
a mockery of the CAA. Despite
acknowledging that BART should be the
installation of SCR and compliance with
a 0.07 lb/MMBtu emission rate for Units
1 and 2, the EPA determined that, when
considering the cost of such controls,
they would not be reasonable. Certainly,
the CAA allows the EPA to consider the
‘‘cost of compliance’’ in setting BART
(42 U.S.C. 7491(g)(2)), but the CAA does
not allow the EPA to completely avoid
requiring BART based on cost
considerations. Here, EPA’s proposal to
approve Wyoming’s SIP with regards to
BART for Jim Bridger Units 1 and 2
amounts to a proposal to require
nothing (if not a proposal to allow an
increase in emissions). In essence,
EPA’s proposal amounts to a
determination that BART is not required
for Jim Bridger Units 1 and 2, even
though Congress clearly stated that
these coal-fired EGUs are subject-toBART. Although Congress allowed the
EPA to consider costs in establishing
BART, the EPA cannot use costs as a
reason to completely forego requiring
BART. Put another way, the EPA cannot
defeat Congress’ intent to require BART
by cobbling together an interpretation of
the CAA that effectively nullifies the
regional haze BART requirements under
the Act.
232 70
FR 39132.
Department of Environmental
Quality Air Quality Division, BART Application
Analysis AP–6040, May 28, 2009, pages 7–9.
233 Wyoming
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Response: We disagree with the
commenter. As discussed elsewhere, we
are basing on approval of the State’s SIP
on a weighing of the five BART factors,
including costs and visibility
improvement.
Comment: EPA’s proposal for Jim
Bridger Units 1 and 2 ‘‘does not meet a
test for being ‘better than BART’. . .
[because] [t]he accelerated installation
of BART at Bridger Units 3 and 4 does
not offset the increased emissions from
delaying SCR installation at Bridger
Units 1 and 2 beyond the normal fiveyear BART window.’’ To date, EPA has
failed to make any demonstration that
its 2013 Proposal would ‘‘achieve
greater reasonable progress than would
be achieved through the installation and
operation of BART.’’ 40 CFR
51.308(2)(i). Moreover, EPA’s proposal
also fails to comply with the ‘‘better
than BART’’ regulatory requirement
mandating that ‘‘all necessary emission
reductions take place during the period
of the first LTS for regional haze’’ which
concludes at the end of 2017. Id. section
51.308(b), (e)(2)(iii). Accordingly, EPA’s
proposal has not satisfied the regulatory
requirements for a ‘‘better than BART’’
alternative.
Response: We agree that EPA’s
proposal does not meet a test for being
better than BART but have not
suggested such a concept in our
proposed or final rulemaking actions.
Comment: EPA’s proposed action on
the Wyoming 308 regional haze SIP
requested comments on whether to
require installation of BART controls on
Jim Bridger Units 1 and 2 by 2021–2022
rather than within the legally required
five-year timeframe mandated by the
regional haze regulations. 77 FR 33054.
EPA is taking comment on the
alternative timeline for SCR installation
in response to PacifiCorp’s claim that
‘‘the schedule for installation of
emission control devices envisioned in
[EPA’s BART proposal] would be
excessively costly and would pose
service interruption risks for electrical
energy customers over a large part of the
region.’’ Recent admissions by a
PacifiCorp official in a separate
Wyoming Public Service Commission
proceeding undermines PacifiCorp‘s
arguments. PacifiCorp argued to the
Wyoming Public Service Commission
that procurement and installation of
multiple SCRs creates both a cost and
time savings, not an increase at Jim
Bridger Units 3 and 4. This fact is also
true for installation of SCRs at Jim
Bridger Units 1 and 2. This PacifiCorp
admission is further proof that EPA
should not permit PacifiCorp to delay
installation of SCRs at Jim Bridger Units
1 and 2 and instead must require
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compliance within five years as is
required by the BART regulations.
Response: We have responded to this
comment in other responses.
Comment: EPA is taking comment on
the alternative timeline for SCR
installation in response to PacifiCorp’s
claim that the schedule for installation
of emission control devices envisioned
in EPA’s BART proposal would be
excessively costly and would pose
service interruption risks for electrical
energy customers over a large part of the
region. EPA acknowledges that BART
for all the units at Jim Bridger is SCR
when the units are considered
individually based on the five factors.
However, EPA suggests that a different
BART determination under the
alternative approach is lawful if the five
factors are considered across all the
units in the PacifiCorp system. Not so.
BART is a source-by-source
determination.
Response: We have responded to this
comment in other responses.
Comment: Considerations of
PacifiCorp’s fleet size and cumulative
costs are outside the five-factor analysis
for BART. Furthermore, PacifiCorp’s
concern about the feasibility of
installing BART controls over its large
fleet is unfounded. With proper
planning, there is no reason to expect
excessive costs or service interruption
due to BART requirements. Indeed,
PacifiCorp’s large number of EGUs
would appear to give PacifiCorp the
unique ability to avoid service
disruptions by maintaining adequate
capacity from operating units while
other units are offline. Further, other
utilities have installed SCR systems on
multiple units within very short periods
of time.
PacifiCorp’s ability to install SCR on
multiple units is also not constrained by
the availability of SCR systems. In
response to questioning of whether
PacifiCorp has had any difficulties
procuring or installing SCR systems,
particularly an SCR for its Naughton
Unit 3 facility, PacifiCorp stated it had
received four proposals from SCR
system suppliers and as such did not
experience notable difficulties
procuring and obtaining the SCR
system. EPA should not modify its
BART proposal for Jim Bridger Units 1
and 2 based on PacifiCorp’s
unsupported claims of hardship.
Response: We have responded to this
comment in other responses.
Comment: The EPA’s re-proposed
Wyoming haze plan reiterates EPA’s
prior finding that BART is SCR for each
Jim Bridger unit considered
individually (78 FR 34756). Based on
the EPA’s five-factor NOX BART
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5185
analyses for Jim Bridger Units 1–4, the
EPA must find that SCR is BART to
meet a NOX emission rate of 0.05 lb/
MMBtu on all four units.
The EPA’s cost-effectiveness analyses
identified costs for SCR on all four
Bridger Units that are within the range
that EPA has identified as reasonable for
other units, including in this same
proposal. 78 FR 34754–57 (SCR costeffectiveness of $2,393/ton on Jim
Bridger Unit 1, $3,015/ton on Unit 2,
$2,961/ton on Unit 3, and $2,492/ton on
Unit 4) as compared with, e.g., 78 FR
34776 (finding cost-effectiveness of
$3,600/ton to $3,900/ton for SCR on
Laramie River Units 1–3 to be ‘‘within
the range of what EPA has found
reasonable for BART in other SIP and
FIP actions’’). However, the EPA’s
estimate of costs is significantly
inflated, and the true costs are even
lower than EPA found because the EPA
used unjustified ‘‘retrofit factors,’’
interest rate, and auxiliary power costs.
The recalculation of costs using what
the commenter believes are corrected
inputs resulted in significantly lower
SCR costs of $1,801 to $1,959/ton at all
four Bridger units. On this basis, SCR is
extremely cost effective on these units.
SCR on these units would afford
substantial visibility benefits. The EPA
has no basis in the BART factors,
including the important factors of
compliance costs and visibility
improvement, to reject SCR as BART on
Bridger Units 1–4.
Response: As discussed elsewhere, we
have responded to the commenter’s
points about how costs are calculated
for the BART units. Regardless, we
determined that SCR was not reasonable
for BART based on our weighing of the
five factors.
Comment: The EPA’s 1st Proposal
from its June 2012 Proposal/2013
Proposal in the Alternative, which
would approve Wyoming’s NOX
emission limits and SCR compliance
timeframes for Jim Bridger Units 3 and
4 and would require Jim Bridger Units
1 and 2 to install SCR within five years
of EPA’s final action on the Wyoming
regional haze plan, would result in
lower NOX emissions on an annual basis
than any of EPA’s other NOX proposals
at the Jim Bridger Power Plant. This
schedule also likely reflects the most
economical installation of SCR at all
four of the Jim Bridger units because the
engineering for SCR installation,
including the design of the construction
phase, can all be done during the same
time frame, the construction equipment
can remain on-site for the duration of
the installations, and much of the
installation work can be done
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simultaneously, which will save on
labor and construction equipment.
There are numerous examples of
installations of multiple SCRs at
numerous units at the same power plant
site over short timeframes, including: (1)
W.A. Parish Units 5–8 (SCRs installed
over 2003–2004); (2) All four units of
the Big Bend power plant (SCRs
installed during 2007–2010); (3) Units
1–5 of the Clifty Creek power plant
(SCRs installed 2002–2003); (4) Winyah
Units 1–4 (SCRs installed in 2005); (5)
Over the period of 2001–2006, TVA has
installed SCRs at 18 units at four power
plants. On this basis, the number and
timing of SCR installations required at
PacifiCorp plants as a result of NOX
BART determinations can be
accomplished, as it has been done
before.
Response: As stated above, we find
that PacifiCorp has not presented
sufficient evidence that the economic
effects of installation of SCR on Jim
Bridger Units 1 and 2 within five years
would affect the viability of continued
plant operations, but based on weighing
of the five factors, we find that it is not
reasonable to require SCR for BART.
Comment: We agree with EPA that
Wyoming’s proposal to require
installation of SCR in 2021 and 2022 as
part of Wyoming’s LTS does not satisfy
the CAA or its implementing
regulations. Having determined that
SCR plus LNBs/SOFA is the best system
of continuous emission control, is cost
effective, and will result in significant
visibility improvement, EPA is required
to find that the controls are BART. 40
CFR 51.308(e)(i)(2)(A). Under the RHR,
BART must be installed ‘‘as
expeditiously as practicable, but in no
event later than five years after approval
of the implementation plan revision.’’
40 CFR 51.308(e)(iv). Thus, EPA lacks
discretion to approve Wyoming’s
proposal to require PacifiCorp to install
BART technology beyond the five-year
time frame.
Response: See responses above.
Comment: PacifiCorp submitted
comments in support of delaying
controls on Jim Bridger Units 1 and 2
until 2022 and 2021 respectively. (EPA
issued a Notice of Data Availability
pertaining to this information on July
24, 2012. 77 FR 43205). The main points
raised in their comments are as
follows: 234
• Because of the size and multi-state
nature of its generation fleet, PacifiCorp
and its customers are unreasonably
impacted by the RHR. PacifiCorp
provides regulated electric service to
234 See July 12, 2012 comments from PacifiCorp
in the docket.
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more than 1.7 million customers in
California, Idaho, Oregon, Utah,
Washington and Wyoming with a net
system capacity of 10,597 megawatts.
PacifiCorp operates 75 generating units
across the western U.S. PacifiCorp owns
and operates 19 coal-fueled generating
units in Utah and Wyoming, and owns
100% of Cholla Unit 4, a coal-fueled
generating unit in Arizona. In addition,
PacifiCorp has an ownership interest in
Craig Units 1 and 2 and Hayden Units
1 and 2 in Colorado.
• As evidenced by the emission
reduction projects which PacifiCorp has
already installed in accordance with the
Utah and Wyoming regional haze SIPs,
PacifiCorp is not opposed to making
emission reductions that are cost
effective for its customers and that
achieve environmental benefits, as
required by law. PacifiCorp has
undertaken projects to comply with the
Utah and Wyoming SIPs at a cost of
approximately $1.3 billion (PacifiCorp’s
share of $1.4 billion of total project
costs) between 2005 and 2011. Those
projects, in conjunction with projects
completed through 2012, have reduced
emissions of SO2 by approximately 58%
and emissions of NOX by approximately
46%.
• Just as modeled visibility
improvements associated with
PacifiCorp’s emission reduction projects
do not stop artificially at a state border,
EPA’s analysis of the impacts of its
proposed FIP for a large, multi-state
system like PacifiCorp’s should not be
limited to only those facilities and
customers located within Wyoming’s
borders. EPA’s actions impacting large,
multi-state systems in one state must
also consider the cumulative impacts of
all of its actions in all other states that
affect the same system.
• Given the number of facilities
operated by PacifiCorp and the facilities
in which the company has an
ownership interest in and is required to
pay costs for the installation of regional
haze-related controls, accelerated and
additional controls under the proposed
FIP result in approximately $500
million of additional capital
expenditures plus an incremental
annual cost of $16–24 million to operate
those controls in the next five years. In
addition, an EPA proposal for stringent
control requirements in Utah (i.e., SCR)
within five years would add
approximately $750 million in capital
expenditures, plus approximately $7
million to $9 million annually in
operating costs and approximately $4
million annually for catalyst
replacement projects. All of these costs
will be put on the backs of PacifiCorp
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and its customers in an extremely shorttime frame.
• In addition to the regional haze
requirements, PacifiCorp’s coal-fueled
generating fleet, including the BARTeligible units, must accommodate
controls for compliance with the
Mercury and Air Toxics Standards
(MATS) during the same timeframe.
While the scrubbers and baghouses
already installed at many of the
PacifiCorp facilities pursuant to the
Utah and Wyoming regional haze SIPs
position the company well to comply
with the acid gas and non-mercury
metals limits under the MATS
requirements, additional work will be
necessary to comply with the mercury
emission limits by April 2015.
• PacifiCorp’s customers cannot
absorb increasing environmental costs.
To accommodate, among other cost
increases, the costs of the environmental
controls already installed on
PacifiCorp’s coal-fueled generating
facilities, PacifiCorp has filed with its
utility regulatory authorities annual
cases to increase customer rates.
PacifiCorp’s customers have
consistently participated in these cases
to express concerns regarding increases
in electric rates. While EPA may view
its proposal to accelerate the installation
of controls and require additional
controls at PacifiCorp’s facilities as just
another utility complaining to avoid the
consequences of large investments in
controls, EPA’s proposal has a very real
impact on customers.
• As a regulated utility, PacifiCorp
has a legal obligation to supply reliable
electric service at reasonable rates as set
by state utility commissions; it also has
a legal requirement to supply its
customers as much electricity as they
want, when they want it. While the
installation of emissions controls on
multiple units in a short period of time
creates substantial challenges from a
project management perspective, these
challenges are exacerbated by increased
risk factors that jeopardize PacifiCorp’s
ability to meet its underlying utility
obligations and challenge the reliability
of the system.
• When considered independently
from other environmental requirements,
the retrofits required under either
regional haze compliance scenario are
not anticipated to impose undue stress
on the national supply chain for
specialized labor, materials, and
equipment. However, analyses of
compliance with the MATS have raised
concerns that requiring much of the U.S.
coal fleet to retrofit or retire in a three
to five year-time frame (partially
overlapping the compliance time period
under the regional haze program) will
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challenge the equipment construction
industry.
• Wyoming and EPA are legally
required to consider the economic and
system impacts on PacifiCorp and its
customers. As EPA’s BART Guidelines
explain: ‘‘There may be unusual
circumstances that justify taking into
consideration the . . . economic effects
of requiring the use of a given control
technology. These effects would include
effects on product prices . . . Where
these effects are judged to have a severe
impact on plant operations you may
consider them in the selection process,
but you may wish to provide an
economic analysis that demonstrates, in
sufficient detail, for public review, the
specific economic effects, parameters,
and reasoning.’’ 70 FR 39171. Given the
large number of BART impacted units
owned by PacifiCorp in different states,
these unusual circumstances justify
Wyoming’s BART actions on
PacifiCorp’s facilities and PacifiCorp’s
customers.
Response: PacifiCorp argues that
springtime scheduling of the unit
outages and outage extensions needed
for ‘‘tie-in’’ of retrofitted controls could
challenge system reliability in certain
years—in PacifiCorp’s forecast, power
demand plus reserves would
temporarily exceed available supply.
EPA believes that this forecast is
unrealistic because PacifiCorp
constrains itself almost entirely to use of
its own generation supplies (ignoring
other available generators in its region)
and limits its assessment to springtimeonly outages in its system-wide outage
planning examples. PacifiCorp indicates
that spring outages are economically
preferred due to the historical
availability of cheap hydro replacement
power and the typically higher
alternative costs of purchased
replacement power at other times.
However, PacifiCorp provides no
information on the availability or net
cost of replacement power to meet
demand, nor does PacifiCorp identify
any alternative retrofit outage schedules.
This is a significant omission because
alternative retrofit outage schedules that
avoid reliability issues through noncoincident temporary uses of purchased
power, even if such temporary power
purchases may cost more than power
typically provided by the facilities
experiencing an outage, might have a
very small levelized net retail cost
impact when applied to customers
system-wide. In short, PacifiCorp ties its
own hands in its provided analysis,
ignoring proven and cost-effective
strategies for maintaining electric
reliability to allow facility upgrades in
a timely fashion.
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EPA notes that PacifiCorp overstates
the purported regulatory burden on its
generating resources by claiming that
the company ‘‘has not yet identified a
viable control suite that will allow it to
comply with the [Mercury and Air
Toxics Standards, or MATS] provisions
at the Carbon plant in Utah. As a result,
while not finally determined, it is
anticipated that Carbon Units 1 and 2
will be required to be shut down in the
2015 timeframe, resulting in the loss of
172 megawatts of generation from
PacifiCorp’s system.’’ Such an
assumption is unfounded and ignores
the EPA’s clear explanation in the final
MATS that under the CAA, state
permitting authorities can also grant
sources an additional year as needed for
technology installation. EPA expects
this option to be broadly available. EPA
is also providing a pathway for
reliability critical units to obtain a
schedule with up to an additional year
to achieve compliance. This pathway is
described in a separate enforcement
policy document.235 As a result, the
comment does not identify any specific
conflict between MATS compliance
planning at the Carbon facility and
regional haze compliance planning at
the Jim Bridger units at issue in this
rule.
In developing their argument,
PacifiCorp borrows a ‘‘WetFGDeq’’
concept that EPA used in its nationwide analysis of the feasibility of
retrofitting all controls that might be
needed for timely compliance with
MATS. PacifiCorp uses EPA’s nationally
applicable WetFGDeq concept to
compare annual WetFGDeq MW
amounts of the limited site-specific
retrofit activity that PacifiCorp has
actually conducted during the past two
decades, and might conduct in the
future under the SIP, to the annual
amount that they might have to conduct
in the future under the proposed FIP.
Based on this comparison, PacifiCorp
states the following (see page 20 of 23;
also see Figure 8 of PacifiCorp’s July 12,
2012 comments): ‘‘The differences
between the SIP Scenario and the
Aggressive BART Scenario are fairly
substantial on an equivalent Wet FGD
basis. In the SIP Scenario, only one year
exceeds the 2010–2011 levels of retrofit
investment (of about 225 MW/year),
while retrofits placed in service in 2017
(675 MW) substantially exceed the
235 Memorandum from Cynthia Giles, Assistant
Administrator of the Office of Enforcement and
Compliance Assurance, ‘‘The Environmental
Protection Agency’s Enforcement Response Policy
for Use of Clean Air Act Section 113(a)
Administrative Orders in Relation to Electric
Reliability and the Mercury and Air Toxics
Standard’’ (Dec. 16, 2011).
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5187
previous historic maximum of 475 MW
by 200 MW and two years are above the
2010–2011 level. The control
installation requirements under the EPA
Aggressive BART Scenario would result
in more work, less time, and increased
costs.’’
EPA does not disagree that the
proposed FIP may entail more
PacifiCorp project management and
construction effort (in one year, 2017)
than the SIP would require, or than
PacifiCorp has actually experienced as
an individual company in the past.
However, EPA does not consider the
relatively small absolute amounts of the
differences (200–300 MW) to be a
serious obstacle for any large utility,
given a bevy of retrofit experience of
this magnitude by like companies in the
past, on similar schedules.
Comment: In making any BART
determinations on a large, multijurisdictional system such as
PacifiCorp’s, the regulating agency must
consider the broad scope of the impacts
of its decisions on customers and
generating system reliability as a whole.
Wyoming considered these factors in
developing its regional haze SIP: ‘‘The
Division believes that the size of
PacifiCorp’s fleet of coal-fired units
presents unique challenges when
reviewing costs, timing of installations,
customer needs, and state regulatory
commission requirements. Information
has been supplied by PacifiCorp
elaborating on additional factors to be
considered in PacifiCorp’s BART
determination (see PacifiCorp’s
Emissions Reductions Plan in Chapter 6
of the Wyoming technical support
document).’’
Wyoming’s consideration of these
factors was appropriate. While
PacifiCorp agrees with EPA’s proposed
conclusions regarding the
reasonableness and timing of
installation of controls at Jim Bridger
Units 1 and 2, EPA’s focus on
affordability impermissibly fails to
consider the unusual circumstances and
broader impacts of its action on
PacifiCorp’s other BART Units. EPA’s
selection of SCR controls at Naughton
Units 1 and 2 and at Dave Johnson Unit
3 will affect the viability of continued
unit operations. Installation of SCR
controls at these three units, particularly
given the cost of controls and their
remaining useful life, create such
‘‘unusual circumstances’’ that justify
taking into consideration the conditions
of the plant and the economic effects of
requiring the use of a given control
technology.
The timing and reasonableness of the
eight SCR and two SNCR and LNBs
required in EPA’s proposed action must
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be considered in the context of the
additional controls required at
PacifiCorp’s units in Arizona (Cholla
Unit 4 with SCR required by 2017) and
its share of units in Colorado (Hayden
Unit 1 with SCR in 2015, Hayden Unit
2 with SCR in 2016, Craig Unit 1 with
SNCR in 2017 and Craig Unit 2 with
SCR required in 2016) and the potential
for additional controls required at four
of PacifiCorp’s BART-eligible units in
Utah within five years after final action.
EPA’s failure to consider the ‘‘unusual
circumstances’’ contemplated under its
Appendix Y Guidance means the agency
acted in a manner that is arbitrary and
capricious in its overall assessment (or
lack thereof) of the effects of its actions
on PacifiCorp’s generation fleet.
Response: See our response to the
comment above.
Comment: Pursuant to 40 CFR
51.308(e), the State included provisions
in its 309(g) regional haze SIP to address
BART. When evaluating each permit
application, the State determined BART
for each source by evaluating visibility
control options presented in the
applications using the methodology
prescribed in 40 CFR part 51, Appendix
Y.
The use of the BART guidelines
contained in Appendix Y is only
required for sources located at EGUs
with a total capacity greater than 750
MW, which for Wyoming were Basin
Electric’s Laramie River Station and
PacifiCorp’s Jim Bridger and Dave
Johnston plants. However, for
consistency, the State chose to follow
the guidelines for all BART sources,
including those located at the trona
facilities. By using the guidelines of
Appendix Y for all sources, the State
established a consistent framework for
performing BART evaluations. Finally,
when selecting the ‘‘best alternative,’’
the State considered additional impacts
to both the plant and the State.
Appendix Y affords the determining
authority discretion to consider
additional impacts. See 70 FR at 39171.
The State’s BART analysis not only
considered all statutory factors, but also
considered the significant impact on
energy costs to PacifiCorp’s Wyoming
rate payers if the controls, including
SCR, were required to be installed in the
BART timeframe of five years after SIP
approval. While the State did not have
the resources to perform a highly
technical and complex analysis to
quantify the potential cost impact of
requiring installation of SCR controls on
all of PacifiCorp’s Wyoming fleet,
additional information was provided by
PacifiCorp for public review.
In addition to identifying costs in
terms of capital expenditures, the State
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also considered the logistical challenges
unique to PacifiCorp. The State is not
aware of any other company faced with
as many potential add-on control
installations as PacifiCorp.
Additionally, the State noted potential
reliability issues related to the extended
downtimes needed for the installation of
SCR systems on multiple units within
the BART timeframe. The impact of
taking down large units, like Jim Bridger
Units 1–4, each rated at a nominal 530
MW, for extended outages increases the
possibility of power shortages, not to
mention increased power cost if
PacifiCorp must purchase additional
power at spot market prices to meet
demand.
Response: The commenter raises
many of the same points that PacifiCorp
raised in its July 12, 2012 comments on
our third proposal in the alternative,
and we have responded to the
commenters points in our response
above. EPA does not find the arguments
for delaying controls put forth by
PacifiCorp or the commenter to be
compelling.
Comment: In making any BART
determinations on a large, multijurisdictional system such as
PacifiCorp’s, the regulating agency must
consider the broad scope of the impacts
of its decisions on customers and
generating system reliability as a whole.
Wyoming considered these factors in
developing its regional haze SIP: ‘‘The
State believes that the size of
PacifiCorp’s fleet of coal-fired units
presents unique challenges when
reviewing costs, timing of installations,
customer needs, and state regulatory
commission requirements.’’ Information
has been supplied by PacifiCorp
elaborating on additional factors to be
considered in PacifiCorp’s BART
determination (see PacifiCorp’s
Emissions Reductions Plan in Chapter 6
of the Wyoming Technical Support
Document). Wyoming’s consideration of
these factors was appropriate. EPA’s
rejection of these factors was not
appropriate.
Given the large number of BART
impacted units owned by PacifiCorp in
different states, these ‘‘unusual
circumstances’’ justify Wyoming and
EPA considering the impact of EPA’s
BART decision-making in the western
U.S. on PacifiCorp and its customers.
Response: We have responded to the
commenter’s points in our responses
above. As stated, EPA does not find the
arguments for delaying controls put
forth by the State or PacifiCorp to be
compelling.
Comment: Congress has defined ‘‘best
available retrofit technology’’ as ‘‘an
emission limitation based on the
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maximum degree of reduction of each
pollutant subject to regulation under
this chapter. . . .’’ 42 U.S.C. 7479(3).
Congress also narrowly defined which
sources would be exempt from BART.
Section 169A(c) of the CAA exempt
fossil fuel power plants exceeding 750
megawatts only if the ‘‘owner or
operator of any such plant demonstrates
to the satisfaction of the Administrator
that such power plant is located at such
a distance from all areas . . . that such
power plant does not or will not, by
itself or in combination with other
sources, emit any air pollutant which
may reasonably be anticipated to cause
or contribute to significant impairment
of visibility in any such area.’’ Id. at
section 7491(c)(2). Any such exemption
must be agreed to by the FLMs. Id. at
section 7491(c)(3). PacifiCorp has not
submitted evidence demonstrating that
the Jim Bridger coal plant—with a net
generating capacity of 2,120 megawatts,
78 FR 34753—will not cause or
contribute to significant visibility
impairment in any Class I area. To the
contrary, EPA’s own visibility modeling
shows that Bridger has significant
visibility impacts at numerous Class 1
areas. 78 FR 34754–34758. As such,
EPA may not exempt the Jim Bridger
plant from BART.
Response: We agree with the
commenter that PacifiCorp has not
submitted any evidence that the Jim
Bridger plant is located at such a
distance from all Class I areas that the
plant will not, by itself or in
combination with other sources, emit
any air pollutant which may reasonably
be anticipated to cause or contribute to
significant impairment of visibility in
any such area.
Comment: EPA should require
installation of SCR at each Jim Bridger
unit within the five-year regulatory
deadline because this approach offers
the greatest visibility improvement.
Response: See responses above.
Comment: EPA proposes that
Wyoming’s determination of NOX BART
for Jim Bridger units 1 and 2 as new
LNB plus OFA is reasonable and that it
would be unreasonable of the EPA to
require any further retrofits at these
units within five years of EPA’s final
action. 78 FR 34756. The State supports
EPA’s proposed approval of NOX BART
as LNB plus OFA for Jim Bridger Units
1 and 2. EPA also proposes to approve
the State’s LTS of NOX control for Jim
Bridger Units 1 and 2 as the SCR-based
emission rate of 0.07 lb/MMBtu with
compliance dates of December 31, 2021,
for Unit 2 and December 31, 2022, for
Unit 1.
Based on facts PacifiCorp raised
concerning the additional requirements
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in the proposed FIP for Wyoming, the
finalized FIP for Arizona, and the
possibility of additional requirements in
a future FIP or SIP for Utah, the
additional time allowed PacifiCorp to
install controls under the State’s LTS on
Jim Bridger Units 1 and 2 is warranted
under the affordability provisions in the
BART Guidelines. 40 CFR part 50, App.
Y, section IV(E)(3); see also 78 FR
34756. Wyoming therefore supports
EPA’s proposed approval.
Response: We disagree with the
points raised by the commenter in the
second paragraph and have addressed
their points in previous responses to
comments. Nonetheless, we are
approving the State’s SIP for Jim Bridger
Units 1 and 2.
Comment: Wyoming strongly urges
EPA to stand by its proposed approval
of Wyoming’s SIP requiring Jim Bridger
Unit 1 to meet the 0.07 lb/MMBtu
emission rate prior to December 31,
2021 and Unit 2 to meet the 0.07 lb/
MMBtu emission rate prior to December
31, 2022. However, Wyoming
encourages EPA to approve Wyoming’s
LTS for Jim Bridger Units 1 and 2 as
submitted, rather than approve only the
SCR portion, in order to preserve future
flexibility for ensuring adequate
emission controls.
Response: We agree with this
comment to the extent that the
regulatory requirements we are adopting
for monitoring, recordkeeping, and
reporting only require that Jim Bridger
Units 1 and 2 meet an emission limit of
0.07 lb/MMBtu on a 30-day rolling
average. Our regulatory language does
not require PacifiCorp to install SCR to
meet these limits. EPA is approving
Wyoming’s LTS for Jim Bridger Units 1
and 2 as submitted.
Comment: EPA acted arbitrarily by
not evaluating SNCR for the Jim Bridger
units. EPA’s proposed regional haze FIP
is defective because EPA did not follow
the BART Guidelines when conducting
a five-factor analysis for potential BART
NOX controls. As the BART Guidelines
explain, states (and EPA when it
substitutes itself for the state) must
evaluate ‘‘the control effectiveness of all
the technically feasible control
alternatives. . . .’’ Here, EPA failed to
do so by not analyzing SNCR for the Jim
Bridger plant. In fact, EPA admits it did
not conduct a full BART analysis for
SNCR for the Jim Bridger units:
‘‘Because of our examination of the
factors lead us to propose SCR as
reasonable for BART, we have
eliminated SNCR for further
consideration.’’
Response: We disagree with this
comment. Our proposed rulemaking
notice clearly shows that we considered
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SNCR in our analysis (see Table 9 and
Table 11 of the proposed rulemaking
action).
Comment: One commenter stated that
our proposed rule creates unnecessary
regulatory uncertainty by saying we
propose to approve the State’s
compliance deadlines for Jim Bridger
Units 1 and 2, but then go on to say we
are seeking comment on a 2017
compliance deadline. They go on to say
that EPA must state unequivocally that
they approve of the State’s existing
compliance deadlines for Jim Bridger
Units 1 and 2.
Response: We have responded to this
comment in previous responses.
Comment: We received numerous
general comments in favor of our
proposed approval of the State’s SIP for
the Jim Bridger Units 1–4.
Response: See responses to other
comments above.
Comment: PacifiCorp supports EPA’s
proposed action to afford ‘‘considerable
deference’’ to the Wyoming SIP with
respect to what controls are reasonable
and when they should be implemented
at Jim Bridger Units 1 and 2, and that
it would be unreasonable to require any
further retrofits at this source within
five years of EPA’s final action. This is
especially true given the extremely
limited visibility improvement that
would be achieved if SCRs were
installed within the BART time period
at Jim Bridger Units 1 and 2.
Further, PacifiCorp does not believe
EPA, having reached the conclusion that
it would be unreasonable to require
further retrofits at Jim Bridger within
five years, can reverse its decision
simply by inviting comment on an
alternative proposal without further
consideration of the broader impacts of
forcing more aggressive controls within
a five-year period.
Response: We have responded to this
comment in previous responses.
Comment: We received numerous
comments that an earlier compliance
deadline for the installation of SCR at
Jim Bridger Units 1 and 2 would be a
significant burden and would be costly
to PacifiCorp consumers.
Response: We have responded to this
comment in other responses to
comments.
Comment: We agree with EPA that
SCR represents BART for all four
Bridger units, but recommend a lower
30-day rolling average emission limit
(e.g. 0.06 lb/MMBtu) to reflect the true
capabilities of SCR.
Response: We have addressed the
control effectiveness of SCR above in
section V.C.3.
Comment: We received comments
that BART for NOX emissions at Jim
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Bridger Units 1–4 must be based on SCR
and LNBs/SOFA, which represents the
best system of continuous emissions
reduction and that commenters agree
with EPA’s proposal to require this
technology as BART. Commenters went
on to state that EPA must revise its
BART-based NOX emission limit for
Units 1–4 from 0.07 lb/MMBtu to no
higher than 0.05 lb/MMBtu, which the
selected technology can easily achieve.
Response: We have addressed the
control effectiveness of SCR above in
section V.C.3.
b. PM BART Determination
Comment: The fabric filter option
discussed by Wyoming represents
PacifiCorp’s estimate that application of
a Compact Hybrid Particulate Collector
unit in addition to using flue gas
conditioning with the existing
electrostatic precipitators can reduce
emissions an additional 50% resulting
in a PM10 emission rate of 0.015 lb/
MMBtu. Considering that EPA Region 9
proposed that the Desert Rock power
plant meet 0.010 lb/MMBtu, we believe
that the Compact Hybrid Particulate
Collector option could achieve the same
limit.
Response: See our response to a
similar comment in section IV.C.6 of
this rulemaking.
Comment: Neither Wyoming nor EPA
completed the five-step BART process
for PM10 emissions. EPA asserted that:
‘‘The State did not provide visibility
improvement modeling for fabric filters,
but EPA is proposing to conclude this
is reasonable based on the high cost
effectiveness of fabric filters at each of
the units. In addition, we anticipate that
the visibility improvement that would
result from lowering the limit from 0.03
lb/MMBtu to 0.015 lb/MMBtu would be
insignificant based on the State’s
analysis.’’
We have several concerns with these
conclusions: (1) EPA cannot simply
abort the five-step process once it has
determined a technology to be
technically feasible; (2) EPA has
overlooked the environmental impact of
SO3 emissions that may be released as
a result of PacifiCorp’s FGC BART
proposal; (3) Wyoming has
underestimated the effectiveness of the
fabric filter option; and (4) Wyoming’s
fabric filter costs are overestimated. For
example, the cost estimates used by
Wyoming contained escalation, extra
contingencies, and AFUDC, which are
not allowed by the CCM and have been
rejected by EPA in other analyses. The
total for these improper costs exceeds $7
million per fabric filter.
Even taken at face value, the cost/ton
deemed ‘‘high’’ by EPA for Units 2 and
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3 are similar to or lower than cost/ton
values accepted as reasonable (for NOX)
by states and by EPA in other analyses.
EPA should complete a proper five-step
PM10 BART analysis by re-evaluating
the Compact Hybrid option on the basis
of its ability to achieve a lower limit
(e.g., 0.010 lb/MMBtu), evaluating costs
in accordance with the BART
Guidelines, comparing its costeffectiveness to other baghouse
installations to properly assess the
‘‘reasonableness’’ of its cost, and
determining the degree of visibility
improvement that would result from a
lower PM10 limit.
Response: See our response to a
similar comment in section IV.C.6 of
this rulemaking.
3. Dave Johnston Units 3 and 4
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a. NOX BART Determination
Comment: Wyoming has
underestimated the ability of SCR to
reduce emissions. In estimating the
annual cost-effectiveness of the
LNB+OFA+SCR option, Wyoming
assumed 0.07 lb/MMBtu on an annual
average basis. Based on the 0.28 lb/
MMBtu NOX emission rate predicted for
the LNB+OFA option, and the 0.23 lb/
MMBtu annual emission rates
demonstrated by Johnston Unit 3 in
2011, outlet emissions at 0.07 lb/MMBtu
represent only a 70%–75% SCR control
efficiency as opposed to the generallyaccepted 90%. Based on the 0.15 lb/
MMBtu NOX emission rate predicted for
the LNB+OFA option, outlet emissions
at 0.07 lb/MMBtu represent only a 53%
SCR control efficiency on Unit 4.
Wyoming has not provided any
documentation or justification to
support the higher emission rates used
in its analyses. In other recent BART
actions, EPA has determined that SCR
can achieve 0.05 lb/MMBtu on an
annual basis. Such an underestimate at
Johnston biases the cost-benefit analysis
against SCR and is inconsistent with
other EPA analyses.
Response: The commenter has
incorrectly assumed that a 90% control
efficiency can be achieved in all SCR
applications regardless of the input NOX
emission rate or other parameters. In
addition, we note that the emission rate
analyzed by Wyoming, 0.07 lb/MMBtu,
was on a 30-day rolling average basis,
not an annual basis. Regardless, we
agree that SCR can in most cases
achieve a performance rate of 0.05 lb/
MMBtu on an annual basis. (See section
IV.C.4 of this rulemaking for more
information on the control effectiveness
of SCR). We have revised the SCR costs
for Dave Johnston Units 3 and 4
accordingly.
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Comment: Wyoming has
overestimated the cost of SCR. A survey
of industry SCR cost data (conducted for
the Utility Air Regulatory Group) and
EPA IPM estimates show that typical
SCR costs for units the size of the
Johnston units would be $180–$300/
kW. Wyoming’s cost estimates for SCR
on Units 3 and 4 are $488 and $436/kW,
respectively, which exceed real-world
industry costs ($50–$300/kW) and
industry estimates, leading us to believe
that capital and annual costs are
overestimated.
Response: See our response regarding
the cost of SCR in section IV.C.5 of this
rulemaking.
Comment: Neither PacifiCorp nor
Wyoming provided justification or
documentation for their cost estimates.
We were not provided with any vendor
estimates or bids, and PacifiCorp and
Wyoming did not use the CCM. For
example, the cost estimates used by
Wyoming contained AFUDC, which is
not allowed by the CCM and has been
rejected by EPA in other analyses. The
total for these improper costs exceeds
$13 million.
Response: In order to address the cost
analysis deficiencies noted by the
commenter, EPA has performed revised
cost analyses for Dave Johnston Units 3
and 4. In our revised cost analyses, we
have followed the structure of the CCM,
though we have used the IPM cost
models to estimate direct capital costs
and O&M costs.
Comment: Dave Johnston Unit 4 could
very likely achieve a NOX rate as low as
0.03 lb/MMBtu, which reflects 80%
NOX control across the SCR. A lower
NOX emission limit would increase the
cost of the total system, but the cost
effectiveness of the system is actually
improved because of the greater NOX
removal. The cost effectiveness of SCR
plus LNBs/OFA at Dave Johnston Unit
4 to meet a 0.03 lb/MMBtu NOX rate
would be $1,803/ton of NOX removed.
EPA should require Dave Johnston Unit
4 to install SCR plus LNBs/OFA to meet
a NOX rate of 0.03 lb/MMBtu or, at
worst, no higher than 0.05 lb/MMBtu.
Response: We have addressed the
control effectiveness of SCR above in
section V.C.3. Again, we have not
selected LNBs with OFA and SCR for
Dave Johnston Unit 4 due to the high
incremental cost effectiveness, when
considered within the context of the five
factors.
Comment: EPA’s use of undefined
incremental cost effectiveness versus
incremental visibility benefit threshold
is arbitrary in concept and in its
application. It is arbitrary in concept
because EPA has not provided any
reasoned basis for its approach let alone
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disclosed the threshold it applies. It is
arbitrary in application, because in the
case of Dave Johnston Unit 4, the
visibility benefits of SCR do justify its
cost, as EPA has found for other units.
Response: We disagree. We have
made our determination based on a
weighing of the five factors. One of the
factors to be considered is costeffectiveness, both average and
incremental. For Dave Johnston Unit 4,
we have determined that the
incremental costs, when considered
with the other BART factors, does not
make the selection of SCR reasonable.
Comment: The EPA failed to support
its conclusion that SNCR, rather than
SCR, is BART for Dave Johnston Unit 4.
The EPA’s sole basis for rejecting SCR
as BART for Dave Johnston Unit 4 was
the incremental cost effectiveness of the
control, which EPA estimated to be
$11,951, but the EPA has not supported
this line-drawing with reference to the
statutory BART factors or purpose of the
regional haze program. Without
providing objective standards or
rationale to support its determination,
the EPA’s judgment that the incremental
cost effectiveness of SCR on Dave
Johnston Unit 4 is too high appears
arbitrary.
The EPA’s analysis of incremental
cost effectiveness for Dave Johnston
Unit 4 also cannot drive the Agency’s
BART determination because EPA
overestimated the cost of SCR for Unit
4. The EPA found the average cost
effectiveness of SCR to be reasonable for
the unit, but the costs are even lower
than the EPA assumed because the EPA
used unjustified ‘‘retrofit factors,’’
interest rate, and auxiliary power costs.
Response: As stated in our response
above, we have made our determination
based on a weighing of the five factors.
One of the factors to be considered is
cost-effectiveness, both average and
incremental. For Dave Johnston Unit 4,
we have determined that the
incremental costs, when considered
with the other BART factors, does not
make the selection of SCR reasonable.
In addition, we have revised the costs
of SCR for Dave Johnston Unit 3 in
support of our final rulemaking. The
revised costs are no longer based on a
retrofit factor, but instead are based on
a budgetary price from an equipment
vendor submitted by PacifiCorp during
the comment period. We feel that use of
the vendor data for SCR provides a more
accurate capital cost than when using a
retrofit factor. For reasons described in
separate responses, we continue to find
that use of the social discount rate of
7% is appropriate for regulatory
applications such as BART
determinations. We have corrected the
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auxiliary power costs to reflect busbar,
and not market price of power; however
this has a small affect on overall costs.
Our cost methodology and assumptions
are described in detail in the cost report
that can be found in the docket.
Comment: SCR on Dave Johnston Unit
4 would likely result in even greater
NOX emission reductions than EPA
assumed, further undermining the
Agency’s exclusive reliance on
incremental cost effectiveness to reject
SCR as BART. An emission rate lower
than 0.05 lb/MMBtu on a 30-day average
is achievable for Dave Johnston Unit 4
because this unit operates combustion
controls that independently control
NOX emissions to a 30-day average of
0.13 lb/MMBtu (compared with the 0.22
lb/MMBtu NOX-emission rate achieved
at Unit 3). At this emission level, SCR
would only need to remove 66.4 percent
of NOX emissions to achieve an
emission rate of 0.05 lb/MMBtu, while
SCR is capable of achieving NOX
reductions of 90 percent. The EPA
should have evaluated the costeffectiveness of SCR on Dave Johnston
Unit 4 based on even greater NOX
emissions reductions that are readily
achievable.
Response: We disagree. First, the
commenter has incorrectly assumed that
a 90 percent reduction in NOX is
achievable with SCR regardless of inlet
rate or other parameters. In most cases,
SCRs are designed for a performance
emission rate, such as in lb/MMBtu, and
not the anticipated percent reduction. In
the case of Dave Johnston Unit 4, the
low emissions currently being achieved
with combustion controls are not an
indication that the SCR would achieve
greater reductions than estimated by
EPA. In fact the exact opposite is true:
the lower the inlet rate to the SCR, the
less NOX that will be removed as there
are simply fewer tons to remove.
Finally, we note that we have revised
our cost calculations to support the
determinations in today’s final rule. In
our revised analysis, we calculate that
the incremental cost effectiveness of
SCR is $13,312/ton, as opposed to
$11,951/ton. This reinforces our
conclusion that SCR is not appropriate
for Dave Johnston Unit 4. Our cost
methodology and assumptions are
described in detail in the cost report
that can be found in the docket.
b. Alternative Control Technology
Proposal
Comment: Dave Johnston Unit 3 was
retrofitted with LNB and separated OFA
in the spring of 2010, and Unit 4 was
retrofitted with the same technology in
early 2009. EPA recognizes that Unit 3
has a current annual NOX emission rate
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of about 0.22 lb/MMBtu, and Unit 4 has
a rate of about 0.14 lb/MMBtu. The
potential additional NOX controls that
may be added to these units include
SNCR and SCR. Should an alternate
control technology be considered by
EPA for Dave Johnston Unit 3, SNCR is
preferable to SCR for Dave Johnston
Unit 3 when considering all currently
available information and the current
emissions performance of the unit.
Even though the cost of SNCR is
unacceptably high for Unit 3
(approximately $5,500 per ton NOX
removed), it is still far less than the
tremendously expensive cost of SCR
($15,769 per ton NOX removed for Unit
3), particularly when taking into
account the incrementally small
modeled visibility improvement
between the technologies.
Response: As described in section
III.B of this document, we have reevaluated the cost of compliance for
Dave Johnston unit 3 to reflect a shorter
remaining useful life (9 years as
opposed to 20 years) because PacifiCorp
has volunteered to install SNCR and
retire the unit in 2027 in lieu of
installing SCR under our proposed rule.
As we explain there, our revised BART
analysis shows that neither SNCR nor
SCR is reasonable over this shorter
remaining useful life. However, our
analysis continues to support a
conclusion that SCR is warranted if the
costs of compliance are calculated over
a 20-year remaining useful life.
Therefore, we have also included an to
give PacifiCorp the option to meet a 0.07
lb/MMBtu emission limit (assumes
installation of SCR) within five years of
today’s action instead of shutting down
the unit.
Comment: With respect to Dave
Johnston Unit 4, EPA has concluded
that SNCR is BART for that unit. As
such, PacifiCorp has only provided
updated SNCR information for Unit 4,
considering all currently available
information and the current emissions
performance of the unit. The cost of
SNCR for Unit 4 is unacceptably high
and not cost effective (approximately
$12,000 per ton NOX removed). The
alternate control technology for Dave
Johnston Unit 4 would be LNB/OFA, as
is currently installed today.
Response: We disagree with the cost
effectiveness estimates provided by the
commenter. Nonetheless, as described
above, in consideration of comments
received during the public comment
period, we have re-evaluated our cost of
compliance estimates for Dave Johnston
Unit 4. Our revised costs, when taken
along with the remaining BART factors,
no longer show that SNCR is warranted
for Dave Johnston Unit 4. Therefore, we
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5191
agree that BART for Dave Johnston Unit
4 is the currently installed combustion
controls (LNB/OFA).
4. Naughton Units 1–3
a. NOX BART Determination
Comment: The EPA proposes to
accept Wyoming’s SIP proposal to
identify SCR as BART on Naughton Unit
3 and to require SCR to reduce NOX
emissions from Naughton Unit 1 and 2.
The EPA properly recognized that the
costs of SCR on Naughton Units 1–3 are
reasonable. However, the EPA’s estimate
of costs is significantly inflated, and the
true costs are even lower than EPA
found because the EPA used unjustified
‘‘retrofit factors,’’ interest rate, and
auxiliary power costs. The recalculation
of costs using what the commenter
believes are corrected inputs resulted in
significantly lower SCR costs of $1,501
to $1,788/ton at all three Naughton
units. On this basis, SCR is very cost
effective on these units and at the low
end of the cost threshold when scanning
NOX reduction costs elsewhere. SCR
also is justified by the visibility benefits
it would afford, which additionally
supports EPA’s findings that SCR
reflects BART for Naughton Units 1–3.
Response: EPA believes that the
retrofit factors used in cost estimates
were reasonable and has described in
detail the reasoning for the retrofit
factors in other responses. EPA also
discussed the reasoning for the assumed
interest rate in responses to other
comments. EPA has revised its cost
estimates and has made changes where
EPA believed that input from
commenters justified changes.
Comment: EPA should evaluate the
feasibility and cost-effectiveness of
further NOX reductions that could be
achieved by a more-efficient SCR. EPA
is proposing that the FIP NOX BART
emission limit for Naughton Unit 1,
Unit 2, and Unit 3 is 0.07 lb/MMBtu
(30-day rolling average). While we are
generally pleased with EPA’s proposal,
we note that EPA’s analysis is based on
only 76% NOX control by the SCRs on
Units 1 and 2, and 85% control by the
SCR on Unit 3. This still results in Unit
2 contributing 0.5 deciviews and Unit 3
contributing 0.9 deciviews to visibility
impairment at Badlands National Park.
Response: We have addressed the
control effectiveness of SCR above in
section V.C.3 above.
Comment: A NOX limit of 0.07 lb/
MMBtu on a rolling 30-boiler operating
day basis would only require Naughton
Units 1 and 2 to achieve 71 percent NOX
removal and Naughton Unit 3 to achieve
80 percent NOX removal across the SCR
system based on an evaluation of
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available CAMD emissions data. A 0.05
lb/MMBtu NOX emission limit
applicable on a rolling 30-boiler
operating day average basis would
require 79 percent NOX removal across
the SCR at Naughton Units 1 and 2 and
85.7 percent NOX removal at Naughton
Unit 3, which is achievable.
Response: We have addressed the
control effectiveness of SCR above in
section V.C.3 above.
Comment: We received comments
that Wyoming has underestimated the
ability of SCR to reduce emissions.
Commenters stated that in estimating
the annual cost-effectiveness of the
LNB+OFA+SCR option, Wyoming
assumed 0.07 lb/MMBtu on an annual
average basis. Based on the 0.026–0.37
lb/MMBtu NOX emission rate predicted
for the combustion control option,
outlet emissions at 0.07 lb/MMBtu
represent only 73%–81% SCR control
efficiency as opposed to the generally
accepted 90%. Commenters went on to
point out that in other recent BART
actions, EPA has determined that SCR
can achieve 0.05 lb/MMBtu on an
annual basis.
Response: The commenters have
incorrectly assumed that a 90% control
efficiency can be achieved in all SCR
applications regardless of the input NOX
emission rate or other parameters. In
addition, we note that the emission rate
analyzed by Wyoming, 0.07 lb/MMBtu,
was on a 30-day rolling average basis,
not an annual basis. Regardless, we
agree that SCR can in most cases
achieve a performance rate of 0.05 lb/
MMBtu on an annual basis. (See section
IV.C.4 of this rulemaking for more
information regarding the control
effectiveness of SCR). We have revised
the SCR costs for the Naughton units
accordingly.
Comment: A survey of industry SCR
cost data (conducted for the Utility Air
Regulatory Group) and IPM estimates
show that typical SCR costs for units the
size of the Naughton units would be
$280–$330/kW. Wyoming’s cost
estimates for SCR are $412–$531/kW,
which exceed real world industry costs
($50–$300/kW) and industry estimates,
leading us to believe that capital and
annual costs are overestimated.
Response: See our response regarding
the cost of SCR in the section V.B.2 of
this rulemaking.
Comment: Neither PacifiCorp nor
Wyoming provided justification or
documentation for their cost estimates.
We were not provided with any vendor
estimates or bids, and PacifiCorp and
Wyoming did not use the CCM. For
example, the cost estimates used by
Wyoming contained AFUDC which is
not allowed by the CCM and has been
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rejected by EPA in other analyses. The
total for these improper costs exceeds
$17 million.
Response: In our revised SCR cost
analysis for the Naughton units, we
followed the framework of the CCM
(although we derived direct capital costs
and O&M costs using the more recent
approach found in the IPM cost
models). For example, we did not allow
for owner’s costs and AFUDC.
Therefore, we have addressed the
concerns raised by the commenter.
b. Alternative Control Technology
Proposal
Comment: EPA requested additional
information on the conversion of
Naughton Unit 3 from a coal fired unit
to a natural gas fired unit. 78 FR 34760.
EPA must evaluate PacifiCorp’s fuel
conversion in accordance with
Appendix Y as a ‘‘better-than-BART’’
alternative and not as a BART control
technology option because EPA had
made clear in its BART Guidance that
‘‘it is not [EPA’s] intent to direct States
to switch fuel forms, e.g. from coal to
gas,’’ as part of the BART analysis. 70
FR 39104, 39164. PacifiCorp voluntarily
submitted its permit application to
convert Naughton Unit 3 to natural gas,
the State issued a federally enforceable
permit requiring such conversion.
Compliance with the permit is therefore
not voluntary.
The permitted NOX performance level
of Naughton Unit 3 after conversion to
natural gas is 0.08 lb/MMBtu based on
a 30-day rolling average and not 0.10 lb/
MMBtu based on a 30-day rolling
average as stated in PacifiCorp’s permit
application. Additionally, the permitted
NOX mass emission rate is 250 lb/hr
based on a 30-day rolling average,
which is protective of visibility and
lower than the BART-determined NOX
rate of 259 lb/hr based on the same
averaging period. Finally, annual NOX
emissions will be reduced from the
BART level of 1,134 tons to 519 tons.
Response: We tentatively agree that
the conversion of Naughton Unit 3 to
natural gas is better-than-BART for that
individual unit, however, the State has
not provided a SIP for EPA’s action on
this option. EPA does not have the
authority to approve the conversion
without a SIP submittal, and is,
therefore, approving the State’s BART
determination for SCR at Naughton Unit
3 without making a final determination
on whether the conversion is betterthan-BART for that unit. In lieu of our
approval of the State’s BART
determination for Naughton Unit 3, EPA
is committed to take expedited action
on a future SIP revision for Naughton
Unit 3 reflecting the conversion if the
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State submits such a revision. That
action would constitute our final
determination on the conversion.
Comment: Rather than install the
control equipment required by the
Wyoming SIP, PacifiCorp will convert
the unit to fire natural gas by the end
of 2017. A construction permit allowing
the conversion has been issued by
Wyoming, and PacifiCorp is moving
ahead with a request for Wyoming to
modify the Wyoming SIP to
accommodate this change. The
construction permit issued by Wyoming
requires Naughton Unit 3 to cease
burning coal by December 31, 2017 and
to be retrofitted to natural gas as its fuel
source by June 30, 2018. PacifiCorp
requests that EPA’s final FIP include
this compliance alternative for
Naughton Unit 3.
Response: See our response above.
Comment: The Conservation
Organizations support the Naughton
Unit 3 conversion to natural gas within
the first five-year regional haze planning
period as a better-than-BART alternative
to installation of SCR on Unit 3. We
recognize that a gas conversion will
virtually eliminate SO2 emissions as
well as greatly reduce NOX and PM
emissions resulting in significant
visibility benefits.
However, to the extent that EPA is
considering whether the Naughton Unit
3 is better than BART as proposed for
all three Naughton Units (i.e., whether
the conversion may be approved
‘‘instead of . . . BART as proposed’’ for
Naughton Units 1 and 2, 78 FR 34783),
the Conservation Organizations object.
The Conservation Organizations
conducted visibility modeling to
determine whether PacifiCorp’s
proposed natural gas conversion at Unit
3 (with LNB and OFA at Units 1 and 2)
would result in greater visibility
improvement than would EPA’s reproposed BART alternative of SCR at all
three Naughton Units. The analysis
shows that EPA’s re-proposed SCR
BART determination consistently
results in greater visibility improvement
over the gas conversion scenario. Thus,
the conversion of Naughton Unit 3 to
gas with LNB/OFA on Units 1 and 2
does not satisfy the ‘‘better-than-BART’’
standards of the regional haze
regulations. Whether or not PacifiCorp
converts Naughton Unit 3 to natural gas,
EPA must require the installation of
SCR to meet an emission limit of 0.05
lb/MMBtu to satisfy BART for Naughton
Units 1 and 2.
Response: We acknowledge the
support for a natural gas conversion as
a better-than-BART alternative for
Naughton Unit 3. If the State submits a
SIP revision reflecting the conversion,
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we will take expedited action on it. As
discussed elsewhere, we are approving
the State’s SIP submittal for all
Naughton Units based on our
consideration of the five BART factors.
The remainder of the comment is
therefore not relevant.
5. Wyodak
Comment: Wyoming has
underestimated the ability of SCR to
reduce emissions. In estimating the
annual cost-effectiveness of the
LNB+OFA+SCR option, Wyoming
estimated 0.07 lb/MMBtu on an annual
average basis. Based on the 0.18 lb/
MMBtu NOX emission rate predicted for
the LNB+OFA option, outlet emissions
at 0.07 lb/MMBtu represent only a 61%
SCR control efficiency as opposed to the
generally-accepted 90%. Wyoming has
not provided any documentation or
justification to support the higher
emission rates used in its analyses. In
other recent BART actions, EPA has
determined that SCR can achieve 0.05
lb/MMBtu on an annual basis. Such an
underestimate at Wyodak biases the
cost-benefit analysis against SCR and is
inconsistent with other EPA analyses.
Response: The commenter has
incorrectly assumed that a 90% control
efficiency can be achieved in all SCR
applications regardless of the input NOX
emission rate or other parameters. In
addition, we note that the emission rate
analyzed by Wyoming, 0.07 lb/MMBtu,
was on a 30-day rolling average basis,
not an annual basis. Regardless, we
agree that SCR can in most cases
achieve a performance rate of 0.05
lb/MMBtu on an annual basis. (See
section IV.C.4 of this rulemaking for
more information regarding the control
effectiveness of SCR). We have revised
the SCR costs for Wyodak accordingly.
Comment: A survey of industry SCR
cost data and EPA IPM estimates show
that typical SCR costs for units the size
of Wyodak would be $180–$280/kW.
Wyoming’s cost estimates for SCR are
$474/kW, which exceed real-world
industry costs ($50–$300/kW) and
industry estimates, leading us to believe
that capital and annual costs are
overestimated.
Response: See our response regarding
the cost of SCR in section IV.C.5 of this
rulemaking.
Comment: Neither PacifiCorp nor
Wyoming provided justification or
documentation for their cost estimates.
We were not provided with any vendor
estimates or bids, and PacifiCorp and
Wyoming did not use the CCM. For
example, the cost estimates used by
Wyoming contained AFUDC, which is
not allowed by the CCM and has been
rejected by EPA in other analyses. The
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total for these improper costs exceeds $8
million.
Response: In our revised SCR cost
analysis for Wyodak, we followed the
framework of the CCM (although we
derived direct capital costs and O&M
costs using the more recent approach
found in the IPM cost models). For
example, we did not allow for owner’s
costs and AFUDC. Therefore, we have
addressed the concerns raised by the
commenter.
Comment: The addition of SCR at
Wyodak should be required because it is
consistent with the other BART
determinations EPA has made. EPA is
proposing that the FIP NOX BART is
new LNBs with OFA plus SNCR at an
emission limit of 0.17 lb/MMBtu. EPA
proposes to eliminate new LNBs with
advanced OFA plus SCR. The
cumulative cost effectiveness of adding
SCR to Wyodak is equivalent to EPA’s
accepted values at Laramie River Unit 2.
Based upon cost and visibility
improvement, we believe that SCR is
BART for Wyodak. As EPA stated in its
notice, ‘‘cost-effectiveness and visibility
improvement are within the range of
other EPA FIP actions.’’ Even though
cumulative visibility improvement is
relatively low, so are SCR costs.
A NOX limit of 0.07 lb/MMBtu on a
rolling 30-boiler operating day basis
would only require Wyodak to achieve
67 percent NOX removal across the SCR
system based on an evaluation of
available CAMD emissions data. A 0.05
lb/MMBtu NOX emission limit
applicable on a rolling 30-boiler
operating day average basis would
require 76 percent NOX removal across
the SCR, which the commenter believes
is achievable.
Response: As a result of other
comments we have received, we are
finalizing a NOX BART determination of
new LNBs with OFA plus SCR for
Wyodak. We agree with the portion of
this comment that states this is
consistent with other EPA BART
determinations. We disagree with the
remainder of the comment. As we have
discussed in other responses, we are not
required, nor have we chosen to, use the
$/deciview metric, let alone the same on
a cumulative basis, when assessing
BART.
We have addressed the control
effectiveness of SCR above in section
V.C.3.
Comment: For Wyodak, EPA is
proposing that the FIP NOX BART is
new LNBs with OFA plus SNCR at an
emission limit of 0.17 lb/MMBtu. EPA
proposes to eliminate new LNBs with
advanced OFA plus SCR because:
‘‘Although the cost-effectiveness and
visibility improvement are within the
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range of other EPA FIP actions, we find
that the cumulative visibility
improvement of 1.16 deciviews for new
LNBs with OFA plus SCR is low
compared to the cumulative visibility
benefits that will be achieved by
requiring SCR at Dave Johnston Unit 3
(2.92 deciview), Laramie River Unit 1
(2.12 deciview), Laramie River Unit 2
(1.97 deciview), Laramie River Unit 3
(2.29 deciview), Naughton Unit 1 (3.54
deciview), and Naughton Unit 2 (4.18
deciview).’’
Because the cumulative visibility
improvement from EPA’s proposed
control strategy is barely half of the
visibility improvement that EPA
rejected as ‘‘low,’’ then visibility
improvement cannot be the only factor
relied upon by EPA in making its BART
determination. We can only conclude
that EPA is somehow relating visibility
improvement to another factor. For
example, after correcting for the
unsupported 1.3 retrofit factor at this
relatively simple, single-EGU facility,
the cost-effectiveness of adding SCR is
$16 million/deciview at Wind Cave
National Park, and $10 million/
cumulative deciview. By comparison,
based upon EPA estimates, addition of
SCR to Laramie River Unit 3 results in
$28 million/deciview at the mostimpacted Class I area, and addition of
SCR to Laramie River Unit 2 yields $10
million/cumulative deciview. The
cumulative cost effectiveness of adding
SCR to Wyodak is equivalent to EPA’s
accepted values at Laramie River Unit 2.
Response: We disagree with the
suggested use of the $/deciview metric.
As we have discussed in other
responses, we are not required, nor have
we chosen to, use the $/deciview
metric, let alone the same on a
cumulative basis, when assessing BART.
Even if we had, the commenter’s
position is predicated on their assertion
that EPA inappropriately applied a
retrofit factor for SCR at Wyodak. As we
have discussed in other responses, we
disagree that it was inappropriate to
apply a retrofit factor of 1.3. However,
as explained below, we agree that we
should not have relied on the basis
stated in our proposal to reject SCR. For
Wyodak, we find that the visibility
improvements at two Class I areas,
when weighed with the other BART
factors, makes SCR reasonable as BART.
Comment: Based upon cost and
visibility improvement, we believe that
SCR is BART for Wyodak. Under the
EPA proposal, Wyodak would still
contribute over 0.7 deciview
impairment at Wind Cave National Park
(and exceed 0.5 deciviews at Badlands
National Park). With the addition of
SCR, impairment would drop to less
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than 0.5 deciviews at all Class I areas.
As EPA stated in its proposal, ‘‘costeffectiveness and visibility
improvement are within the range of
other EPA FIP actions.’’ Even though
cumulative visibility improvement is
relatively low, so are SCR costs.
Addition of SCR at Wyodak should be
required because it is consistent with
the other BART determinations EPA has
made here.
Response: After further consideration,
we agree that it was inappropriate for
EPA to reject SCR as BART for Wyodak
based on the rationale that Wyodak’s
emissions affect fewer Class I areas than
Wyoming’s other BART-eligible sources.
Where consideration of the five factors
demonstrates that a control is
reasonable in light of the visibility
improvement that will occur at the most
impacted Class I area, as was the case
here for Wyodak and Wind Cave, the
fact that additional Class I areas will
also experience visibility improvement
can only bolster the case for that
control’s selection, not undermine it. In
other words, the fact that Wyodak’s
emissions affect two Class I areas
instead of six or seven is irrelevant if the
improvement at just one Class I area is
sufficient to warrant a control’s
selection as BART. Consequently, we
have reassessed the five factors for
Wyodak and now conclude, even after
taking into account our revised cost
estimates and visibility modeling, that
LNB/OFA + SCR is NOX BART for
Wyodak Unit 1.
Comment: SCR with an emission limit
of 0.05 lb/MMBtu should be required as
NOX BART for Wyodak, rather than an
SNCR-based limit of 0.17 lb/MMBtu as
EPA proposes. EPA properly recognized
that the cost-effectiveness and
incremental cost-effectiveness of SCR to
reduce Wyodak’s NOX emissions are
reasonable, but nonetheless proposed to
reject SCR on the basis of purportedly
insufficient cumulative visibility
benefits. EPA’s proposed determination
is improper, because EPA has failed to
justify why incremental visibility
benefits over the large number of Class
I Areas impacted by Wyodak’s NOX
emissions should not be required to
achieve reasonable progress toward the
national visibility goal, particularly in
light of the fact that none of the
Wyoming Class I areas affected by
Wyodak’s NOX emissions are projected
to achieve the Uniform Rate of Progress
(URP) in 2018. Moreover, while EPA
evaluated the impacts of Wyodak’s NOX
emissions only at Wind Cave and
Badlands National Parks, our
supplemental modeling shows that SCR
to control Wyodak’s NOX emissions will
nearly eliminate the plant’s perceptible
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visibility impacts at 18 Class I areas.
EPA’s visibility justification for rejecting
SCR as BART was improper because
Congress has directed EPA to require
BART ‘‘for the purpose of eliminating or
reducing any [visibility] impairment’’
caused by the source. 42 U.S.C.
7491(b)(2)(A). Installing SCR at Wyodak
would resolve this impairment.
Response: See our response to the
previous comment. While we do not
agree with the commenter’s assertion
that Wyodak’s emissions have
perceptible visibility impacts at 18 Class
I areas or that the URP is relevant for
purposes of a BART determination, we
do agree that our decision to eliminate
SCR based on cumulative visibility
improvement was improper.
Comment: EPA properly recognized
that the cost-effectiveness and
incremental cost-effectiveness of SCR to
reduce Wyodak’s NOX emissions are
reasonable, but nonetheless proposed to
reject SCR on the basis of purportedly
insufficient cumulative visibility
benefits. EPA’s estimate of costs is
significantly inflated, and the true costs
are lower than EPA found because the
EPA used unjustified ‘‘retrofit factors,’’
interest rate, and auxiliary power costs.
On these bases, the EPA should require
SCR at Wyodak as BART.
Response: See our previous two
responses.
6. Trona Mines
a. FMC Westvaco and General Chemical
Green River
Comment: EPA should reconsider
whether SCR plus combustion controls
is BART for the FMC Westvaco Units
NS–1A and NS–1B. At $3,493/ton, as
presented by EPA, SCR may be a costeffective option. Furthermore, EPA
should evaluate whether the cost of SCR
for FMC Westvaco Units NS–1A and
NS–1B were calculated correctly.
Response: Although EPA has not reevaluated the cost of SCR at the FMC
Westvaco Units, we note the relatively
low visibility improvement from SCR
for each unit (0.24 deciviews). Because
of the low visibility improvement from
SCR, we do not find that a
reconsideration of costs would
necessarily have led EPA or the State to
a different conclusion regarding the
selection of SCR.
Comment: At a minimum, EPA must
require SNCR and LNB + SOFA as
BART for NOX at the Westvaco plant.
EPA determined that this enhanced
technology could achieve a 0.21 lb/
MMBtu NOX emissions rate. This would
result in a 70% reduction in NOX
emissions from current levels, rather
than just a 50% reduction that would
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result from the 0.35 lb/MMBtu emission
rate currently proposed. Requiring
SNCR would lead to NOX emissions
reductions of 1,903 tpy. SNCR in
addition to LNB+SOFA is highly cost
effective at $673/ton. This is well within
the range of BART costs that EPA has
found reasonable for SNCR at other
facilities, including facilities in
Wyoming. For example, EPA proposes
to reject Wyoming’s NOX BART
proposal for Wyodak Unit 1, and instead
to require LNB+OFA+SNCR as BART,
finding the technology cost effective at
$958/ton, a higher cost than the same
technology at the Westvaco boilers.
Response: We disagree with this
comment. First, SNCR at each of the
units would achieve a 0.19 deciview
improvement, with an incremental
visibility improvement of 0.06
deciviews. The cost effectiveness for
LNBs compared to LNBs with SNCR is
more than double ($304/ton compared
to $673/ton). Based on this information,
we find it reasonable for the State not
to determine SNCR is BART for these
units based on a consideration of the
five factors, including the visibility
improvement.
Comment: Requiring SNCR at the
FMC Westvaco plant would improve
visibility at affected Class I areas. EPA
states that Wyoming’s visibility
modeling for this facility demonstrated
a 0.19 deciview improvement at the
Bridger Wilderness Area from the
installation of SNCR on each boiler. In
fact, Wyoming’s modeling demonstrated
a 0.198 deciview visibility improvement
for the maximum 98th percentile impact
at Bridger Wilderness Area. The
combined visibility improvement due to
SNCR at both Westvaco boilers is nearly
0.4 deciviews at the Bridger Wilderness
Area alone. EPA found it appropriate to
consider the combined visibility impact
of pollution controls on multiple units
at a single facility in determining that
BART is SNCR for Units 1 and 2 of the
Colstrip facility in Montana and should
likewise consider the combined
visibility impact of SNCR on the two
Westvaco boilers.
Response: We have addressed a
similar comment above in section V.B of
this rulemaking. We recognize that there
may be some efficiencies in installing
SNCR on two units (e.g., a common
reagent supply system), but expect that
this would provide only a modest
reduction in annual costs. We do not
find that the combined benefit for the
two FMC Westvaco boilers, 0.4
deciviews, is a basis for requiring SNCR.
Comment: Wyoming’s modeling also
showed that SNCR could virtually
eliminate the visibility impairment at
the Bridger Wilderness Area caused by
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the FMC Westvaco Units NS–1A and
NS–1B, reducing the number of days of
noticeable visibility impairment caused
by each boiler from eleven to just one.
Visibility in the Bridger Wilderness
Area is presently diminished by 4.6
deciviews from natural conditions and,
under EPA’s proposed action, it will not
achieve natural conditions until 2165. A
0.4 deciview visibility improvement at
the Bridger Wilderness Area is
particularly significant in light of new
sources of haze-causing pollution from
the oil and gas industry that will affect
this area. NOX emissions from Wyoming
oil and gas development are expected to
more than double in the current regional
haze planning period, from 14,725 tpy
in 2002 to 34,142 tpy in 2018, yet EPA
does not propose any NOX emissions
reductions from this sector.
Accordingly, it is imperative for
Wyoming and EPA to reduce NOX
emissions from every other source to the
greatest extent possible, including by
requiring SNCR to be installed at the
FMC Westvaco Units NS–1A and NS–
1B.
Response: We disagree with this
comment. BART is a source-by-source
analysis taking into consideration the
five factors. The BART Guidelines and
RHR do not require states or EPA to take
into consideration the state being able to
achieve the URP for a Class I area in its
determination of BART for individual
BART units.236
Comment: Wyoming’s modeling,
upon which EPA relied, excluded all
Class I areas beyond 300 km from the
Westvaco facility. However, there is no
demonstration that Class I areas further
afield are not impacted by the Westvaco
facility. As a comparison, EPA recently
approved the South Dakota regional
haze SIP which includes BART limits
for the Big Stone facility, for which the
nearest Class I area is over 400 km away.
Response: We explained in response
to another comment the reasons why we
did not evaluate visibility impairment at
Class I areas at distances greater than
300 km. Regarding the South Dakota
regional haze SIP, there are no Class I
areas within 300 km of the Big Stone
Facility. Therefore, it was reasonable for
236 In determining the measures necessary to
make reasonable progress and in selecting RPGs for
mandatory Class I areas within Wyoming, the State
took into account the following four factors into
consideration: Costs of compliance; time necessary
for compliance; energy and non-air quality
environmental impacts of compliance; and
remaining useful life of any potentially affected
sources. CAA section 169A(g)(1) and 40 CFR
51.308(d)(1)(i)(A). 40 CFR 51.308(d)(1)(ii) allows for
a slower rate of improvement in visibility than the
URP, as long as it is demonstrated that based on
these four factors, it is not reasonable to achieve the
URP and that the selected RPG is reasonable. CAA
section 169A(g)(1) and 40 CFR 51.308(d)(1)(i)(A).
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the state to evaluate visibility impacts at
the nearest Class I area even though the
distance was greater than 300 km. We
note that the BART rule provides some
flexibility to the states in the approach
used to evaluate visibility impairment.
The fact that South Dakota chose to
evaluate visibility impacts at a distance
greater than 300 km does not impose a
similar requirement on other states.
Comment: Considering just the two
Class I areas modeled, the installation
and operation of SNCR would result in
a cumulative maximum 98th percentile
visibility improvement of 0.304
deciviews from each unit, or 0.608 from
both units combined. This cumulative
visibility improvement at two Class I
areas is significant and amply justifies
SNCR, at a minimum, as BART.
Response: In the proposed rule, we
did focus on the visibility benefits at the
most impacted Class I area. We
considered the visibility benefits at the
other Class I areas, but did not consider
the benefits sufficient to warrant a
change in our determination as to the
appropriate level of control.
Comment: Although the cost
effectiveness and visibility
improvements due to SNCR and
LNB+SOFA standing alone justify a
determination that this combination of
technologies is BART, EPA apparently
agreed with Wyoming that the
incremental costs of requiring SNCR
were not justified by the resulting
visibility improvement. EPA’s
consideration of incremental cost
effectiveness and visibility benefit is
arbitrary given the lack of any objective
criteria and in any event, must not be
viewed in a vacuum.
Response: We disagree with this
comment. As stated above, we find it
reasonable, based on a consideration of
the five factors, including the low
visibility improvement, for the State to
find that SNCR and LNBs was not
reasonable for BART.
Comment: Although the State and
EPA determined that addition of
combustion controls is BART for the
three BART boilers at these two
facilities, it is unclear how they arrived
at these conclusions. The visibility
improvement from EPA’s proposed
controls for the trona plants are less
than the visibility improvement that
EPA rejected as ‘‘low’’ in the EGU BART
analyses, so it appears that EPA is using
different criteria for these facilities or
relating visibility improvement to
another factor, which we assume to be
some combination of cost and visibility
improvement. (Otherwise, one would
always choose the control strategy with
the greatest visibility improvement.)
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However, it appears that EPA did not
evaluate the cost analyses presented by
the companies and the State, so we are
concerned that the cost analyses for
these two trona plants may suffer for the
same problems that we pointed out to
EPA before regarding the EGUs. For
example, although Boiler D at Green
River is the same size as the FMC
boilers: (1) FMC evaluated addition of
new combustion controls in
combination with SNCR or SCR, Green
River did not. (2) The capital cost of
adding SNCR at Green River Boiler D is
more than four times FMC. (3) EPA
presented cost-effectiveness of SNCR as
$3,176/ton at Green River Boiler D. The
actual cost-effectiveness, based on
EPA’s annual cost and emission
reduction, is $1,637/ton. (4) FMC
assumed that SCR could reduce NOX by
31% to 0.10 lb/MMBtu, Green River
assumed 80% NOX reduction to
0.14 lb/MMBtu. (EPA typically assumes
that SCR can achieve 0.05 lb//MMBtu
on an annual basis.) (5) SCR capital cost
is $43 million at FMC, $19 million for
Green River Boiler D. (6) EPA presented
cost-effectiveness of SCR as $3,510/ton
at Green River Boiler D. The actual costeffectiveness, based on EPA’s annual
cost and emission reduction, is $2,339/
ton.
It is apparent that EPA must have
been considering the costs of controls,
but, in view of the substantial
discrepancies noted above, those costs
are questionable. In view of these
discrepancies, we question how EPA
rejected the more-effective control
technologies (SNCR and SCR) that
produce greater visibility improvements
for the proposed controls.
Response: We disagree with this
comment. Even if the cost of SNCR and
SCR were reduced, we find that the
visibility improvement (Boiler C—0.08
deciviews for SNCR and 0.14 deciviews
for SCR; Boiler D—0.12 deciviews for
SNCR and 0.17 deciviews for SCR)
would not warrant the selection of postcombustion controls for BART.
b. FMC Granger Trona Mine
Comment: EPA proposes to approve
Wyoming’s determination that the FMC
Granger trona mine, while BARTeligible, is not subject-to-BART. The
basis for EPA’s proposed approval is
that the visibility impact of this facility
at the Bridger Wilderness Class I area
would be 0.39 deciviews, and EPA
proposes to ‘‘agree with Wyoming that
0.5 deciviews is a reasonable threshold
for determining whether its BARTeligible sources are subject-to-BART.’’
EPA should reconsider its
determination that the Granger facility
is not subject-to-BART. In making the
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subject-to-BART determination at least
three considerations must be
incorporated pursuant to EPA’s BART
guidelines: Whether the source causes
or contributes to visibility impairment
in a Class I area, the number of
emissions sources affecting a Class I
area, and the magnitude of the
individual source impacts. Wyoming
determined that the Granger plant was
not subject-to-BART because its
visibility impairment level at the
Bridger Wilderness was predicted to be
0.39 deciviews—below the 0.5 deciview
threshold. Wyoming’s determination
was flawed however because it
apparently did not consider the other
factors essential to a subject-to-BART
determination, i.e., the number of
emissions sources affecting the Class I
area and the magnitude of the
individual sources’ impacts.
There are a large number of pollution
sources affecting visibility in the Bridger
Wilderness Area, including significant
impacts from thousands of operating oil
and gas wells that are not BARTeligible. This fact highlights the need for
maximum feasible emissions from each
source contributing to impairment at the
Bridger Wilderness Area, particularly
sources like the FMC Granger trona
mine, which is eligible for BART
controls.
Response: We disagree with this
comment. Wyoming used a contribution
threshold of 0.5 deciviews for
determining which sources are subjectto-BART. By using a contribution
threshold of 0.5 deciviews, Wyoming
exempted seven of the fourteen BARTeligible sources in the State from further
review under the BART requirements.
Based on the modeling results, the State
determined that P4 Production, FMC
Granger, and OCI Wyoming had an
impact of .07 deciviews, 0.39 deciview,
and 0.07 deciview, respectively, at
Bridger Wilderness. Black Hills Neil
Simpson 1, Sinclair Casper Refinery,
and Sinclair—Sinclair Refinery have an
impact of 0.27 deciview, 0.06 deciview,
and 0.12 deciview, respectively, at
Wind Cave. Dyno-Nobel had an impact
of 0.22 deciview at Rocky Mountain
National Park. These sources’ modeled
visibility impacts fell below the State’s
threshold of 0.5 deciview and were
determined not to be subject-to-BART.
Given the relatively limited impact on
visibility from these seven sources, we
continue to agree with Wyoming that
0.5 deciviews is a reasonable threshold
for determining whether its BARTeligible sources are subject-to-BART. In
addition, the commenter points to the
impacts from oil and gas at Class I areas.
The BART Guidelines do not require
states to consider the impacts from
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sources other than BART-eligible
sources when defining the threshold for
determining what sources are subject-toBART. While the Guidelines first say
that, in setting a contribution threshold,
states should consider the number of
‘‘emissions sources’’ affecting the Class
I area at issue, the Guidelines then go on
to clarify that states may use a lower
contribution threshold based on the
location of a large number of ‘‘BARTeligible’’ sources within the State that
are proximate to the Class I area at issue.
E. Reasonable Progress
1. RPGs
Comment: 40 CFR 51.308(d)(1) of the
RHR requires states to establish goals (in
deciviews) that provide for reasonable
progress towards achieving natural
visibility conditions for each Class I area
of the state. These are goals, not
standards. Goals are typically
understood as levels aimed for but not
necessarily met. Early on in the process,
EPA considered setting ‘‘presumptive
targets’’ but eliminated them before the
final rule. EPA also says that the RPGs
established by the state are not directly
enforceable. In spite of this, EPA has
proposed to FIP the Wyoming RPGs.
EPA does not specifically define the
word ‘‘goal,’’ but the RHR does describe
what must be considered when the goals
are set. Wyoming has set six reasonable
progress goals and every one of them
met that criteria. EPA does not even
argue with this basic fact. When setting
the goals, the state must do a reasonable
progress analysis. The State of Wyoming
complied with this requirement as well.
Response: EPA disagrees with this
comment. Wyoming’s selected RPGs do
not meet the requirements of the RHR.
In establishing RPGs, Wyoming must
make two demonstrations. First, the
State must demonstrate how the four
statutory reasonable factors, as applied
to potentially affected sources, were
taken into consideration in selecting the
goals. 40 CFR 51.308(d)(1)(i). In
addition, if Wyoming establishes an
RPG that provides for a slower rate of
improvement than the URP, the State
must demonstrate, based on the four
statutory reasonable progress factors,
that achieving the URP is not reasonable
and that the selected RPG is reasonable.
40 CFR 51.308(d)(1)(ii). In determining
whether the selected RPGs in fact
provide for reasonable progress towards
natural visibility conditions, EPA must
evaluate these two demonstrations. 40
CFR 51.308(d)(iii).
EPA’s interpretation of the statute and
the RHR is that BART sources should
also be identified as anthropogenic
sources of visibility impairment for
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purposes of developing the long-term
strategy. 40 CFR 51.308(d)(3)(iv).
Correspondingly, BART sources should
be considered ‘‘potentially affected
sources’’ and evaluated for controls
using the reasonable progress factors.
See 40 CFR 51.308(d)(1)(i)(A). However,
due to the similarity of the reasonable
progress and BART factors, it is
reasonable for states to rely on their
BART determinations to fulfill the
requirements of 51.308(d)(1)(i)(A) and
51.308(d)(1)(ii) (if applicable), in other
words to demonstrate that the
reasonable progress factors were
reasonably considered for those sources
for the first planning period. This
interpretation is consistent with
guidance EPA has issued for states
regarding meeting reasonable progress
requirements.237 However, the
Wyoming submittal states that the
reasonable progress ‘‘four factor analysis
. . . is a method for evaluating potential
control strategies for facilities that are
not eligible for Best Available Retrofit
Technology (BART) or better-thanBART programs.’’ Wyo. 309(g)
Submittal at 115. Thus, the Wyoming
submittal on its face fails to meet the
requirements of the statute and the RHR.
To the extent that Wyoming can be said
to have relied on its BART
determinations to establish that the
State reasonably considered the
reasonable progress factors for those
sources, that reliance fails for those
sources for which we are disapproving
the BART determinations. In addition,
as the State’s RPGs fall short of the URP,
the State failed to adequately
demonstrate, based on the four statutory
reasonable progress factors, that
achieving the URP was not reasonable
and that, the selected RPG is reasonable.
Given our evaluation of these
demonstrations, we have determined
that the selected RPGs do not provide
for reasonable progress towards natural
visibility conditions.
In addition, although we are not
disapproving the State’s ultimate
determination to not impose controls on
non-BART sources, we note that (as
explained in more detail below) the
State unreasonably relied on
impermissible factors to reach those
determinations. Thus, the State failed to
demonstrate that it was reasonable,
based on consideration of the statutory
reasonable progress factors, to not meet
the URP. In other words, although we
are approving the State’s decision as
part of its long-term strategy to not
237 US EPA, Office of Air Quality Planning and
Standards, Guidance for Setting Reasonable
Progress Goals Under the Regional Haze Program
(June 1, 2007).
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impose controls on the non-BART
sources the State listed, we are still
disapproving the State’s RPGs.
Because the State failed to meet the
requirements of 51.308(d)(1)(i) and (ii)
when the State selected its RPGs as part
of the State’s Regional Haze SIP, EPA is
obligated to promulgate a regional haze
FIP to meet those requirements. That the
RPGs are named ‘‘goals,’’ not standards,
and are not directly enforceable is
irrelevant to this obligation.
Comment: Wyoming explained to
EPA that Wyoming could not compel
these reasonable progress sources to put
on controls without a State rule, and
that rule would have to include a
visibility impact analysis. Wyoming was
willing to commit to developing such a
rule in the next planning period, but it
did not have the time or resources left
to complete that task and get the SIP
submitted to the EPA for the first
planning period. Wyoming’s
administrative rulemaking process
requires about nine months to a year to
develop and finalize rules. Wyoming
believes that it has taken an important
first step in the process, and it appears
to be more than many other states were
making.
Wyoming also believes that it made
more sense to develop a comprehensive
State reasonable progress rule that could
be used for the next SIPs to address
regional haze. That rule would take
extra time that EPA was not willing to
give the State. EPA told the State
repeatedly that ‘‘The Regional Haze
Rule does not allow for commitments to
potentially implement strategies at some
later date that are identified under
reasonable progress.’’ The State is still
dumbfounded by this kind of response
for a rule that goes out to 2064,
especially where EPA itself has
recognized the one-step-at-a-time
doctrine.
Response: EPA disagrees with this
comment. While we understand the
State’s position on its limits on its
authority, time, and resources, EPA first
promulgated the reasonable progress
requirements under the RHR on July 1,
1999, and we issued our guidance on
setting RPGs in September 2007.
Wyoming submitted its Regional Haze
SIP on January 12, 2011. Wyoming does
not explain why the State did not have
an adequate amount of time to develop
a regional haze SIP that meets the
requirements for reasonable progress.
In any case, the State’s limits on its
authority, time, and resources are not
permissible factors for EPA to take into
account when assessing the State’s
Regional Haze SIP. Instead, we must
assess whether it meets the
requirements of the RHR, and in
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particular the requirements for
reasonable progress towards natural
visibility conditions. We note that we
are approving certain portions of
Wyoming’s Regional Haze SIP with
respect to reasonable progress
requirements.
To the extent that the notion of ‘‘onestep-at-a-time’’ is relevant in this
context, as explained elsewhere,
Wyoming’s Regional Haze SIP fails to
adequately make the very first step
towards natural visibility conditions:
Achieving reasonable progress during
the first planning period. A commitment
to completing that first step in a future
planning period cannot substitute for
actually completing the first step within
schedule. Wyoming cites no authority to
the contrary; conditional approval
under CAA section 110(k)(4) does not
apply as Wyoming has made no
commitment to adopt specific
enforceable measures within one year to
remedy the deficiencies. Again,
whatever the constraints imposed on the
State by time, resources, and authority,
those constraints cannot be taken into
account in assessing whether the State
has met the requirements for the first
planning period. In this case, Wyoming
has not met those requirements with
respect to reasonable progress.
Comment: States are required, when
setting RPGs, to determine the rate of
progress needed to attain natural
visibility conditions by 2064. The State
did that and included it in the SIP.
EPA’s RHR also requires that if the rate
is slower than the rate established by
drawing a straight line between baseline
visibility and natural conditions, that it
must be explained why. The data clearly
show that the primary reason that the
State will not reach natural conditions
by 2064 is that smoke from wildfires
controls the slope of the line.
Response: EPA disagrees with this
comment, which understates the
requirements of the RHR for setting
RPGs. We agree that Wyoming did
appropriately determine the URP
needed to attain natural visibility
conditions by 2064 and we are
approving that determination. However,
when a state selects an RPG that
provides for a slower rate of
improvement in visibility than the URP,
it is not the case that all the state must
do is ‘‘explain why.’’ Instead, the state
must demonstrate, based on the
statutory reasonable progress factors as
applied to potentially affected sources,
that the URP is not reasonable and that
the selected RPG is reasonable. 40 CFR
51.308(d)(1)(ii). Under the RHR, 40 CFR
51.308(d)(1)(iii), and under section 110
of the Act (as discussed elsewhere) we
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are required to evaluate the state’s
demonstration.
As discussed elsewhere, the State did
not reasonably consider the statutory
reasonable progress factors for
potentially affected sources. As a result,
the State also failed to adequately
demonstrate, based on the four statutory
reasonable progress factors as applied to
potentially affected sources, that
achieving the URP was not reasonable
and that the selected RPG is reasonable.
We therefore are disapproving
Wyoming’s selected RPGs.
With respect to the comment’s
reference to wildfires, we provide a
detailed response to comments relating
to wildfires and natural conditions in
the modeling section of this response to
comments.
Comment: EPA cannot remove the
reasonable progress goals for the State.
Wyoming followed the process outlined
in the RHR. EPA is not following the
RHR by proposing a control requirement
for a specific source to replace six RPGs
for an entire state. The RHR does not
allow for the substitution of RPGs with
control strategies. EPA’s proposed
disapproval is contrary to law.
Response: EPA disagrees with this
comment. As discussed above, we are
disapproving the State’s selected RPGs
because they do not meet the
requirements of the RHR. In addition,
the commenter is mistaken in stating
that EPA is ‘‘replacing’’ RPGs with
control requirements for a specific
source. This statement conflates two
separate but related requirements of the
RHR. First, states must set RPGs in
accordance with 40 CFR 51.308(d)(1).
Second, states must submit a LTS,
including enforceable emissions
limitations, compliance schedules, and
other measures as necessary to achieve
the RPGs. 40 CFR 51.308(d)(3).
We are disapproving Wyoming’s RPGs
because they do not meet the
requirements of 51.308(d)(1), as detailed
above. Separately, we proposed to
disapprove Wyoming’s determination to
not impose enforceable emissions
limitations at Dave Johnston Units 1 and
2. Thus, we did not propose to
‘‘replace’’ the RPGs with control
requirements; instead, we proposed to
provide both. However, as explained
elsewhere, on the basis of the cost and
visibility information that EPA
developed, we are now approving
Wyoming’s determination (although not
the State’s rationale) to not impose
enforceable emissions limitations at
Dave Johnston Units 1 and 2. We
nonetheless continue to disagree with
the comment.
Comment: There is no way Wyoming
can control the impacts from wildfire
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smoke on visibility. Therefore, it will be
a very long time, 126 to 161 years,
before controlling manmade sources can
ever overcome the smoke impacts, and
that is assuming that smoke impacts
never increase. The length of time for
other western states is even longer, and
EPA has approved those SIPs. Wyoming
included this explanation along with
identifying other sources that impact
visibility, but EPA disagreed with the
Wyoming assessment, saying not all
reasonable controls were implemented
during the first planning period.
Specifically, EPA disagreed with
Wyoming’s determination to not impose
controls on Dave Johnston Units 1 and
2. Because Wyoming did not impose
controls on Dave Johnston Units 1 and
2, EPA has proposed to disapprove
Wyoming’s RPGs.
Wyoming believes that EPA’s
reasoning for disapproving the State’s
RPGs is flawed and arbitrary. First, the
State set goals based on regional
modeling projections done for the entire
western U.S. To the best of our
knowledge, that is the same process that
every other state in the western U.S.
used and many of them now have
approved RPGs in spite of the fact that
it will take hundreds of years in all of
the western Class I areas to reach
‘‘natural conditions.’’ In North Dakota,
for example, it will take between 156
and 232 years to reach natural
conditions at affected Class I areas. It
would be impossible to set deciview
goals without regional modeling, unless
the State wanted to wildly guess at it.
Response: EPA disagrees with this
comment. We are not disapproving
Wyoming’s RPGs solely on the basis that
they fall short of achieving the URP.
Instead, as explained above, we are
disapproving them on the basis that the
State has failed to demonstrate that the
four statutory reasonable progress
factors were appropriately considered.
The State has also failed to demonstrate,
again based on the four statutory
reasonable progress factors, that
achieving the URP is unreasonable and
that the State’s selected RPGs are
reasonable. The comment’s reference to
wildfires is beside the point, as the
existence of wildfires does not relieve
the State of all responsibility to
reasonably consider the statutory
reasonable progress factors for
potentially affected sources. We
elsewhere provide a detailed response
to comments relating to wildfires and
natural conditions in the modeling
section of this response to comments.
Comment: While EPA ‘‘anticipates’’
that controls at Dave Johnston Units 1
and 2 would result in measurable
visibility improvement in regional
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modeling demonstrations, and that
‘‘anticipation,’’ not modeling, therefore
justifies dispensing with Wyoming’s
RPGs, Wyoming does not. When the
WRAP modeled all of the emission
reductions from the entire western U.S.
(including Wyoming emission
reductions for all of the pollutants) for
this first planning period, Wyoming saw
an improvement of 0.6 deciviews at the
Yellowstone site, and a 0.5 deciview
improvement at the North Absaroka and
Bridger sites on the worst days. The
numbers are even smaller or zero for the
best days. These improvements from
much larger emission reductions for
multiple pollutants are almost
imperceptible. Therefore, it is highly
unlikely that emission reductions for
NOX from two units would make
enough difference to show up as an
‘‘improvement’’ in regional scale
modeling, and thereby justify setting
different RPGs.
Response: We disagree with the
approach suggested in this comment.
Below, we discuss the use of CALPUFF
(instead of the regional scale modeling
the comment suggests) to determine
visibility improvement from controls on
Dave Johnston Units 1 and 2. We also
respond to comments regarding regional
scale modeling in section V.B.
Comment: The EPA proposes to
impose reasonable progress controls on
Dave Johnston Units 1 and 2, more
stringent NOX BART controls on Dave
Johnston Unit 3, Jim Bridger Units 1 and
2, Wyodak Unit 1, and Laramie Units 1,
2, and 3. These EPA proposed controls
are more stringent than what was
assumed by the WRAP in modeling
Wyoming’s RPGs. Wyoming established
its RPGs based on the regional modeling
projections completed in the WRAP
process. In proposing these reasonable
progress controls, EPA is also proposing
RPGs that are consistent with the
controls, thereby rejecting Wyoming’s
proposed RPGs.
In rejecting Wyoming’s RPGs and
imposing its own, EPA did not re-run
the WRAP model; instead, the agency
essentially guessed ‘‘that the additional
controls would result in an increase in
visibility improvement during the 20%
worst days,’’ thereby warranting the
more stringent controls at these units.
EPA’s proposal to reject Wyoming’s
RPGs is not warranted. First, the mere
assumption that additional controls will
result in greater visibility improvement
cannot reasonably be supported without
modeling data. EPA admits that it ran
no modeling that would support its best
guess that visibility would improve with
the installation of more stringent
controls. Second, EPA’s proposal to
place controls on the Dave Johnston
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Units 1 and 2 is flawed. The Dave
Johnston Units 1 and 2 are not BARTeligible units. When Wyoming
considered the WRAP model data, it
concluded that putting controls on the
Dave Johnston Units 1 and 2 would not
result in an improvement in visibility.
Without any improvement in visibility
coming from placing controls on these
non-BART units, Wyoming reasonably
concluded that there was no reason to
change its RPGs.
Response: We disagree with this
comment. WRAP performed regional
photochemical modeling using both the
CMAQ and CAMx air quality models to
evaluate progress toward attaining
visibility goals using all projected
emission changes from all source
categories throughout the United States.
WRAP did not perform regional
photochemical modeling to evaluate the
visibility impacts of individual BART
sources. While WRAP did make
assumptions regarding the level of
emissions control that would be
adopted by BART sources, no state or
EPA region has re-run the WRAP’s
regional photochemical models to assess
individual BART source contributions
to visibility impairment. Instead, the
BART sources, the states, and EPA have
used the CALPUFF model to evaluate
contributions to visibility impairment
from individual BART sources. As
discussed earlier in this rulemaking and
the docket for this final action, EPA
modeled visibility impairment from
individual sources in making its
determination of BART and reasonable
progress controls. Thus, the comment is
inaccurate in stating that EPA ran no
modeling to assess whether controls on
Dave Johnston Units 1 and 2 would
improve visibility. With respect to the
assertion that Wyoming considered the
WRAP model data and decided that the
data showed controls on Dave Johnston
Units 1 and 2 would not improve
visibility, the Wyoming SIP submittal
does not reflect that. In evaluating the
reasonable progress factors for Dave
Johnston Units 1 and 2 (which was
selected by the State as a potentially
affected source) the SIP submittal states:
‘‘LNB or LNB w/OFA seem to be the
most reasonable choice[s] for the Dave
Johnston Electric Generating Station
boilers BW41 and BW42 based on the
four factor analysis. The
implementation of new control
technologies on the two boilers are
discussed in further detail in Chapter 8
(Section 8.3.4), Long-Term Strategy.’’
Nonetheless, in section 8.3.4, the SIP
stated: ‘‘The Air Quality Administrator
cannot, per Wyoming Statute 35–11–
202, establish emission control
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requirements except through State rule
or regulation. Furthermore, the
Wyoming statute requires the
Administrator to consider the character
and degree of injury of the emissions
involved. In this case, visibility
modeling would be required to assess
the degree of injury caused by the
emissions. Modeling is not available at
this time to determine impacts from
emission reduction.’’ As we explain
elsewhere, these are not permissible
reasons to ignore the four statutory
reasonable progress factors.
Nonetheless, our revised visibility
modeling leads us to the conclusion that
it was not unreasonable for the State to
not impose controls on Dave Johnston
Units 1 and 2, even though the State’s
basis for doing so was inadequate.
Comment: Wyoming’s adoption of an
alternative SO2 program, even if it were
valid, does not relieve Wyoming of its
obligation to develop and implement a
LTS that includes measures necessary to
reduce visibility-impairing emissions of
SO2, PM, and NOX to achieve RPGs for
non-Colorado Plateau Class I areas.
Accordingly, EPA must determine
whether Wyoming’s RPGs for its nonColorado Plateau Class I areas are
adequate.
Response: We agree that Wyoming
must develop a LTS to address
reasonable progress for non-Colorado
Plateau Class I areas. As our proposed
notice indicates, we proposed to
disapprove the State’s RPGs. We also
proposed to implement additional
controls under reasonable progress. We
are completing the action to disapprove
the State’s RPG’s today, and as
explained elsewhere in this section, we
are not finalizing requirements for
additional controls under reasonable
progress.
Comment: With the exception of the
controls required on Naughton Unit 3,
PacifiCorp has installed all of the BART
controls required by the Wyoming
BART permits and the regional haze
SIP. These controls were installed from
2005 through 2012. The actual
monitored visibility impairment
demonstrates that Wyoming has made
significant progress in reducing nitrate
concentrations and further demonstrates
that the RPGs are on track through the
2008–2017 planning period. EPA’s FIP
is not ‘‘necessary’’ to meet RPGs for
nitrates in these Class I areas. As a
result, EPA should withdraw its FIP.
Response: EPA disagrees with this
comment. As explained above, the State
was required to assess the four statutory
reasonable progress factors for
potentially affected sources and
reasonably determine potential controls,
and we are required to evaluate the
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State’s determination. The State did not
demonstrate reasonable progress for
those determinations that we are
disapproving. As a result, we must
disapprove the State’s RPGs and
promulgate a FIP for them. We also note
that the comment does not explain the
relationship between the State’s RPGs
and changes in monitored visibility
impairment as the result of installed
controls, as the State’s RPGs were not
remodeled to reflect the controls
selected by the State.
Comment: Any discussion of the
appropriate NOX control levels required
under the RHR should include an
assessment of the existing visibility
levels to understand what pollutants are
driving visibility impairment in
Wyoming. Measured visibility
impairment at Wyoming’s IMPROVE
monitoring stations shows that the
contribution from nitrates, which are
visibility impairing pollutants that
result from NOX emissions, play a lesser
role in visibility impairment in
Wyoming than particulate organic mass
or sulfates. The latest available
IMPROVE data (2000–2009) from the
WRAP Technical Support System
reveals the following about the two
Class I areas that were most closely
examined for impacts from Wyoming
BART sources: (1) Currently, the air in
those Class I areas is very clear, with
overall visibility among the best in the
entire country; (2) When visibility is not
good, i.e., when you can’t see across the
vista, it is likely because of smoke from
wildfires; (3) The contribution to
visibility impairment from nitrate
particles, which are as a result of
emissions of NOX, is small.
The State believes it has made a good
case that fire contributes more to
visibility impairment than nitrates at
Class I areas most affected by Wyoming
sources. The State has made great
progress in reducing the manmade
contribution to visibility impairment
from power plants, even when the
manmade contribution has much less
impact to visibility impairment than
other components. EPA’s proposed
disapproval and FIP are not supported
by a record that demonstrates small
visibility improvements predicted by a
CALPUFF model replete with
uncertainty when the actual, measured
levels of nitrates at Class I areas affected
by those sources is so small. Wyoming’s
SIP is adequately supported because
Wyoming considered these and other
factors in arriving at the selected levels
of NOX controls for Wyoming sources
and the schedule for the installation of
those controls.
Response: We disagree with this
comment. Regardless of the
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considerations presented in the
comment, the State was required, at a
minimum, to evaluate the four statutory
reasonable progress factors for
potentially affected sources and to
reasonably determine controls, and we
are required to evaluate the State’s
determination. In evaluating the factors
for Dave Johnston Units 1 and 2, which
was selected in the State’s SIP as a
potentially affected source, the SIP
submittal states: ‘‘LNB or LNB w/OFA
seem to be the most reasonable choice[s]
for the Dave Johnston Electric
Generating Station boilers BW41 and
BW42 based on the four factor analysis.
The implementation of new control
technologies on the two boilers are
discussed in further detail in Chapter 8
(Section 8.3.4), Long-Term Strategy.’’
Nonetheless, in section 8.3.4, the SIP
stated: ‘‘The Air Quality Administrator
cannot, per Wyoming Statute 35–11–
202, establish emission control
requirements except through State rule
or regulation. Furthermore, the
Wyoming statute requires the
Administrator to consider the character
and degree of injury of the emissions
involved. In this case, visibility
modeling would be required to assess
the degree of injury caused by the
emissions. Modeling is not available at
this time to determine impacts from
emission reduction.’’
As explained above, it is unreasonable
and impermissible for the State to
disregard its four factor analysis on the
basis that the State lacked the necessary
modeling and that reasonable progress
requirements could be postponed until
the next planning period. The
considerations presented by the
comment do not change this.
In addition, section 110(a)(2)(E)(i) of
the Act requires that SIPs provide
necessary assurances that, among other
things, the State has adequate authority
and resources to carry out the plan. The
SIP language we quote above instead
denies that the State has the proper
authority and resources to meet the
requirements of the RHR, in particular
the requirement that the long-term
strategy ‘‘include enforceable emissions
limitations . . . and other measures as
necessary to achieve the reasonable
progress goals.’’ 40 CFR 51.308(d)(3). As
a result, Wyoming’s Regional Haze
submittal fails to meet the requirements
of section 110(a)(2)(E)(i), which is
applicable to ‘‘[each] implementation
plan submitted by a State under [the
CAA],’’ including the Regional Haze
submittal.
Comment: An area of the RHR that is
unusual is in the timing of the
implementation of the rule. It is the
most forward looking of all the rules
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with requirements to be carried out by
the grandchildren of the people who are
currently working on the rule, with an
end date of 2064. While EPA has
established long-term targets through
the acid rain program and ozone
attainment requirements in a 10–20 year
time frame, they have never set goals
that were 60 years down the road. This
is significant because EPA recognized
that the problem was complicated and
that it would take at least this much
time to solve it.
EPA’s strategy included breaking up
the long-range goal of achieving natural
conditions by 2064 into many smaller
pieces. EPA included a requirement for
states to submit comprehensive SIP
revisions in 2018 and every ten years
thereafter. In addition to the
comprehensive SIP revisions, states will
also be required under 40 CFR 51.308(g)
to submit progress reports in the form of
a SIP revision every five years, with the
first revision due in 2013. Between both
the comprehensive SIP revisions and
the progress report SIP revisions, states
will be working on 16 more SIP
revisions, at a minimum, to address
regional haze. The State views these
upcoming SIP revisions on regional
haze as opportunities to build on the
first SIP, and that the current rush by
the EPA to get so many reductions
procured in the first time period as
unnecessary. It is unnecessary because
the State has submitted a plan to reduce
NOX from BART sources by 45,153 tons,
and an additional 19,677 tons through
the LTS in the first planning period.
There are few states in the country that
can demonstrate this magnitude of
emission reductions Wyoming has
secured.
EPA recognized in the RHR preamble
that many factors will change over time
and that it may be possible to procure
emission reductions in the future that
cannot be accomplished during an
earlier period. EPA expected reductions
to occur over time and did not expect
states to front end load this program
with emission reductions.
The RHR provides states with the
time necessary to intelligently address
the very complicated problem of
regional haze. Wyoming asks EPA to
recognize their own intentions to roll
out this program step by step and
approve the State’s decision to require
SCR on PacifiCorp Units 1 and 2 of the
Jim Bridger Power Plant in 2021 and
2022 as part of the LTS. The State also
asks that EPA give the State the time it
needs to create a rule to address
reasonable progress, which would
include reductions at the PacifiCorp
Dave Johnston Plant, Units 1 and 2.
Wyoming plans to create a general
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reasonable progress rule in the next
planning period to address future
reductions.
Response: While we recognize the
emission reductions achieved by the
State for the first planning period and
that the regional haze program is a longterm program, the State must still meet
the requirements of 40 CFR 51.308 for
the first planning period. As we stated
in our proposal notice, the State’s plan
does not fully meet the requirements for
BART and reasonable progress. Because
we have found that the State’s SIP
submission did not adequately satisfy
the RHR requirements in full, we have
not only the authority, but a duty to
promulgate a FIP that meets those
requirements. The EPA disagrees that
the additional emission reductions
required by our proposed FIP are
unnecessary, as we have demonstrated
that the State’s SIP does not meet the
requirements of 40 CFR 51.308. Our FIP
action is only intended to ensure that
CAA requirements are satisfied in
accordance with our authority under the
CAA.
Comment: We received numerous
comments that monitoring data shows
that the worst visibility days are due to
wildfires and that EPA should be
focusing on these emissions and not on
nitrate emissions from stationary
sources, which have little impact on
poor visibility days. One commenter
pointed out data from Class I areas in
Wyoming that show organic carbon and
elemental carbon, which are indicators
of wildfire, are major contributors on
poor visibility days compared to
nitrates. Another commenter stated that
the only EPA policy to address fires is
the Interim Air Quality Policy on
Wildland and Prescribed Fires which
has not been updated since 1998 and
that the EPA is not taking action on this
core issue.
Response: While we agree that
industrial facilities are not the only
causes of haze, we disagree with the
thrust of this comment. We provide a
detailed response to comments relating
to wildfires and natural conditions in
the modeling section of this response to
comments. Regardless of the
contribution from wildfire emissions, 40
CFR 51.308(d)(3)(iv) states, ‘‘The State
must identify all anthropogenic sources
of visibility impairment considered by
the State in developing its long-term
strategy. The State should consider
major and minor stationary sources,
mobile sources, and area sources.’’ As
discussed elsewhere, in its submittal the
State identified a number of stationary
sources as potential contributors to
visibility impairment (i.e. potentially
affected sources). The State was
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required, at a minimum, to evaluate the
five statutory BART factors and four
statutory reasonable progress factors for
potentially affected sources and to
reasonably determine controls, and we
are required to evaluate the State’s
determination. 40 CFR 51.308(e) and 40
CFR 51.308(d)(3)(iv), respectively. The
requirements of 40 CFR 51.308(d)(3)(iv)
and 40 CFR 51.308(e) are not dependent
on the showing of a certain amount of
impairment from point sources.
Comment: The CAA and the RHR
require SIPs to set forth goals, expressed
in deciviews, that assure ‘‘reasonable
progress toward meeting the national
goal’’ of ‘‘natural visibility conditions
[in Class I areas] by the year 2064.’’ 42
U.S.C. 7491(a)(4), (b); 40 CFR
51.308(d)(1)(i)(A). The goals ‘‘must
provide for an improvement in visibility
for the most impaired days over the
period of the implementation plan and
ensure no degradation in visibility for
the least impaired days over the same
period.’’ 40 CFR 51.308(d)(1). To
establish these goals, a state must also
‘‘[a]nalyze and determine the rate of
progress needed to attain natural
visibility conditions by the year 2064,’’
by ‘‘compar[ing] baseline visibility
conditions to natural visibility
conditions [in Class I areas] and
determin[ing] the uniform rate of
visibility improvement’’ necessary to
achieve natural conditions by 2064. 40
CFR 51.308(d)(1)(i)(B).
Wyoming’s SIP meets these
requirements. See SIP, at 114–31. The
SIP calculates and compares baseline
and natural visibility conditions, Id. at
114–15, analyzes the rate of progress
needed to attain natural visibility
conditions by 2064, Id., and establishes
a uniform rate of progress, Id. Wyoming
also ensured improvement in visibility
on the most impaired days and no
degradation on the least impaired days.
See Id. at 115 (Table 7.2.1). And, most
importantly, the SIP establishes
reasonable progress goals. Id. at 127–
131. The CAA and the RHR also require
states to make reasonable progress
determinations for particular sources by
‘‘[c]onsider[ing] the costs of compliance,
the time necessary for compliance, the
energy and non-air quality
environmental impacts of compliance,
and the remaining useful life of any
potentially affected sources, and
includ[ing] a demonstration showing
how these factors were taken into
consideration in selecting the goal.’’ 40
CFR 51.308(d)(l)(i)(A).
Wyoming also met this requirement.
The SIP clearly explains how Wyoming
considered these factors and identified
sources impacting visibility in Class I
areas. See SIP, at 116–17. Wyoming then
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explained in its SIP how it applied the
factors to each individual source. See Id.
at 117–27. The SIP therefore meets the
requirements of the Act and the RHR.
Response: As discussed elsewhere, we
have evaluated Wyoming’s BART and
reasonable progress determinations and
we are disapproving them for Dave
Johnston Unit 3, Wyodak Unit 1, and
Laramie River Station Units 1–3.
Because the State did not reasonably
consider the statutory BART factors for
these sources, the State also failed to
adequately demonstrate (to the extent
that the State relied on its BART
determinations to demonstrate the
required consideration of the reasonable
progress factors) that the reasonable
progress factors were appropriately
considered in establishing the RPGs.
The State also failed to adequately
demonstrate, based on the statutory
BART and reasonable progress factors,
that achieving the URP was not
reasonable and that the selected RPG is
reasonable. Given our evaluation of
these two demonstrations and the
comments received, we have
determined that the selected RPGs do
not provide for reasonable progress
towards natural visibility conditions.
In making this determination, we are
not limited to merely noting whether
the State has submitted an analysis that
purports to consider the BART and
reasonable progress statutory reasonable
progress factors. Instead, we evaluate
whether the State reasonably assessed
the statutory BART and reasonable
progress factors as applied to potentially
affected sources and, based on those
factors, reasonably determined whether
controls were required for this planning
period. In this case, the State did not do
so.
As discussed earlier, because the State
failed to meet the requirements of
§ 51.308(d)(1)(i) and (ii) when the State
selected its RPGs as part of the State’s
Regional Haze SIP, EPA is obligated to
promulgate a regional haze FIP to meet
those requirements.
We do agree that the State did
correctly calculate and compare
baseline and natural visibility
conditions, analyzed the rate of progress
needed to attain natural visibility
conditions by 2064, and established a
URP. We agree that Wyoming’s SIP
ensured improvement in visibility on
the most impaired days and no
degradation on the least impaired days,
as does our FIP.
Comment: EPA acknowledges that
Wyoming evaluated the requisite four
factors in its reasonable progress
determinations. 78 FR 34785. But, EPA
asserts that Wyoming incorrectly
calculated costs in those
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determinations. Id. EPA, however, does
not explain how Wyoming incorrectly
calculated costs. EPA asserts first that
‘‘EPA’s rationale for disapproving the
State’s reasonable progress
determination[s] . . . can be found in
Section VIII.B of [the proposal].’’ ld. at
34763. Section VIII.B—the location of
EPA’s supposed ‘‘rationale’’—only
reiterates EPA’s general allegation of
deficiencies in the control cost
estimates. Id. at 34785. EPA therefore
has not described with any meaningful
degree of specificity the supposed errors
that justify rejecting the State’s
reasonable progress determinations.
EPA’s failure to provide an intelligible
justification for its action is unlawful
and arbitrary, and precludes Wyoming
from offering a more meaningful
response.
Response: We disagree. First, the
commenter fails to fully disclose EPA’s
proposed rationale for disapproving the
State’s reasonable progress
determination for Dave Johnston Units 1
and 2. The commenter cites language
related to our finding of deficiencies
with the State’s cost analysis (at 78 FR
34785), but fails to cite our fuller
explanation for disapproving the State’s
determination a few pages later (at 78
FR 34787): ‘‘We disagree with the
State’s reasoning for not adopting
reasonable progress controls for Dave
Johnston Unit 1 and Unit 2. If the State
determined that it needed to adopt a
rule or perform modeling to adequately
assess and, if warranted, require
reasonable progress controls, the State
should have completed these steps
before it submitted its regional haze SIP.
The RHR does not allow for
commitments to potentially implement
strategies at some later date that are
identified under reasonable progress or
for the State to take credit for such
commitments.’’
We offered this rationale in response
to the State’s argument that no controls
were reasonable because: (1) the State’s
four factor analysis was limited, in that
no guidance was provided by EPA for
identifying significant sources and EPA
did not establish contribution to
visibility impairment thresholds (a
potential fifth factor for reasonable
progress determinations), (2) the State
cannot, per Wyoming Statute 35–11–
202, establish emission control
requirements except through State rule
or regulation, (3) the Wyoming statute
requires the State to consider the
character and degree of injury of the
emissions involved—information that
State claimed not to have, and (4) the
State believes it has taken a strong and
reasonable first step in identifying
potential contributors to visibility
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impairment, and that the next step of
creating an appropriate rule or
regulation will be accomplished in the
next SIP revision. 78 FR 34786.
Therefore, our proposed rationale for
disapproving the State’s reasonable
progress determination for Dave
Johnston extended beyond our concerns
with the cost analysis.
Even so, contrary to the commenter’s
assertions, and though perhaps not to
the level of detail desired by the
commenter, we did sufficiently explain
our concerns with deficiencies in
Wyoming’s cost analyses, including
those for Dave Johnston Units 1 and 2.
Most notably, as described in Section
VII.C of the proposed rule, we
recognized that Wyoming had
understated ‘‘the ability of SCR to
reduce NOX.’’ This was most
pronounced at Dave Johnston Units 1
and 2 where the State assumed that SCR
would only reduce NOX to an emission
rate of about 0.09 lb/MMBtu (equivalent
to an 80% reduction from 2001–2003
baseline). As we have established
elsewhere in response to comments, in
this instance SCR has the ability to
reduce NOX to an emission rate of 0.05
lb/MMBtu or less. Therefore, it is clear
that the State underestimated the
emission reductions that can be
achieved with SCR, and thereby
miscalculated the cost effectiveness.
And while EPA did not find that SCR
was warranted for Dave Johnston Units
1 and 2, it was nonetheless necessary to
correctly calculate the cost effectiveness
of all of the technically feasible controls
in order to rationally evaluate the State’s
decision to not impose any controls and
to (had we been compelled to impose a
FIP) select from among competing
control options.
Comment: The RHR clearly states that
every implementation plan must
include reasonable progress goals. 40
CFR 51.308(d)(l). Those goals must be
expressed in deciviews and must
provide for visibility improvement on
the most impaired days and no
degradation on the least impaired days
during the planning period. Id. In EPA’s
own words, RPGs are ‘‘[t]he vehicle for
ensuring continuing progress towards
achieving the natural visibility goal,’’ 78
FR 34743, which is the focal point of the
regional haze program, see 42 U.S.C.
749l(a)(l).
EPA proposes to disapprove the
State’s reasonable progress goals. 78 FR
34767. In the same sentence, EPA
claims to be proposing a FIP to replace
those goals, which EPA asserts can be
found in Section VIII.C of the notice.
Section VIII.C reveals, however, that
EPA has in fact failed to establish
replacement RPGs. See Id. at 34788.
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EPA does not set forth RPGs in
deciviews, nor does it provide for
visibility improvement on the most
impaired days with no degradation on
the least impaired days. See Id. Instead,
EPA merely ‘‘anticipates’’ that its FIP
would lead to improved visibility. Id.
EPA’s anticipation falls far short of the
plain requirements of the RHR—
concrete, deciview-based reasonable
progress goals that provide for improved
visibility on the worst days and no
degradation on the best days. EPA’s
failure to establish RPGs to replace the
SIP goals EPA proposes to disapprove is
therefore unlawful.
EPA justifies its failure to establish
the requisite RPGs by explaining that it
‘‘could not re-run the modeling due to
time and resource constraints [.]’’ Id.
This excuse stands in stark contrast to
EPA’s response to similar claims the
State raised in the context of reasonable
progress. For example, the State
explained to EPA that the State could
not complete its evaluation of the
impacts to visibility from oil and gas
sources until the WRAP completes its
emission inventory study. Id. at 34764–
34765. EPA responded that ‘‘If the State
determined that additional information
was need . . . the State should have
developed the information.’’ Id. at
34765. Similarly, the State explained to
EPA that it needed to conduct
additional modeling before it could
justify controls for the Mountain
Cement kiln. Id. at 34765–34766. Again
setting forth its dual standard, EPA
responded that ‘‘If the State determined
that it needed to adopt a rule or perform
modeling . . . the State should have
completed these steps before it
submitted its regional haze SIP.’’ Id. at
34766.
Response: EPA disagrees with this
comment to the extent it argues that we
should approve the State’s RPGs. We
note that the State did not, in setting its
RPGs, re-run its modeling to reflect the
State’s selected controls. Instead, the
State relied on WRAP modeling that
reflected certain generic assumptions
about the level of controls. See Wyo.
309(g) SIP, pages 53 and 127. As we
have explained elsewhere, regardless of
how the State quantified its RPGs, they
cannot be approved, as the State failed
to appropriately consider the four
statutory reasonable progress factors for
the sources the State selected as
potentially affected sources. See 40 CFR
51.308(d)(1)(i)(A). In addition, the State
cannot rely on the BART determinations
that we are disapproving to show
reasonable progress for those sources.
Because we must disapprove the State’s
RPGs, and RPGs are a required
component of a regional haze SIP, we
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must promulgate our own. We note that
the RPGs are not directly enforceable. 40
CFR 51.308(d)(1)(v). The elements that
directly impact sources and visibility
are the emissions limitations in the
long-term strategy, including those for
BART and those for the reasonable
progress sources.
Comment: When determining the
responsibility for regional haze,
Sweetwater County strongly believes
that the DEQ and EPA need to
investigate the contribution to
Wyoming’s haze problem by sources
located outside of the United States,
especially from countries like China that
do not appreciate the necessity for
strong environmental regulations. If we
do not consider the effects of air
pollution contributing to our nation’s
and our State’s air quality issues, we
open the door for unfair competition. To
assign the entire cost of Wyoming’s haze
and air pollution to Wyoming industries
without considering the effects of
offshore sources is unfair to our
industries, and it would cause
unnecessary impacts to the economy of
Wyoming and the United States.
Response: While sources outside
Wyoming do contribute to haze in the
Class I areas within Wyoming, that does
not preclude the State’s or our
obligation to evaluate sources within the
State according to the five BART factors
and the four reasonable progress factors
and to require additional controls where
necessary. In addition, we note that the
State did evaluate the sources of
contribution to Class I areas in the State
(see e.g., Chapter 5 of the SIP).
Comment: One commenter stated that
EPA must re-evaluate its method for
assessing visibility impacts from
wildfires or states will never be able to
achieve natural background goals. The
commenter went on to say that EPA
should (1) eliminate the impacts from
fire from the annual contribution to the
deciview analysis or (2) properly
incorporate it into the natural
background equation to establish a glide
path states can achieve. The commenter
provided graphical data from the
IMPROVE network to show the
contributions to light extinction from
organic carbon, elemental carbon, and
nitrate.
Response: EPA does recognize this
issue and has taken it into consideration
in this action on the Wyoming SIP and
in our final FIP. We agreed that
Wyoming did appropriately determine
the URP needed to attain natural
visibility conditions by 2064 and we are
approving that determination. We are
not disapproving Wyoming’s RPGs
solely on the basis that they fall short of
achieving the URP. Instead, as
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explained above, we are disapproving
them on the basis that the State has
failed to demonstrate that the four
statutory reasonable progress factors
were appropriately considered. As
stated previously, regardless of the
contribution from wildfire emissions, 40
CFR 51.308(d)(3)(iv) states, ‘‘The State
must identify all anthropogenic sources
of visibility impairment considered by
the State in developing its long-term
strategy. The State should consider
major and minor stationary sources,
mobile sources, and area sources.’’ As
discussed elsewhere, in its submittal the
State identified a number of stationary
sources as potential contributors to
visibility impairment (i.e. potentially
affected sources) and was required, at a
minimum, to evaluate the five statutory
BART factors and four statutory
reasonable progress factors for
potentially affected sources and to
reasonably determine controls, and we
are required to evaluate the State’s
determination. 40 CFR 51.308(e) and 40
CFR 51.308(d)(3)(iv), respectively.
2. Reasonable Progress Sources
a. Oil and Gas Sources
Comment: We received comments
that volatile organic compound (VOC)
emissions from the oil and gas industry
must be controlled under reasonable
progress. Commenters asserted that EPA
acknowledged that oil and gas sources
emit haze-causing VOCs but
inexplicably failed to analyze whether
reducing such VOC emissions is
reasonable. One commenter pointed out
that EPA has just designated Sublette
County (and portions of Sweetwater and
Lincoln Counties) in nonattainment
with the 8-hour ozone national ambient
air quality standard, so there is no doubt
the ozone levels in Sublette County are
of great concern. Commenters pointed
out that ozone severely impairs
visibility; the failure to consider
strategies to limit oil and gas industry
VOC emissions was a significant
oversight on both the part of the State
and EPA. Thus, commenters concluded
that EPA must correct this problem by
analyzing and imposing reasonable
progress controls on oil and gas industry
VOC emissions.
Commenters pointed out that there
are numerous opportunities to reduce
VOC emissions from the oil and gas
industry. These include requiring all oil
and gas fields in the State to control
VOC emissions to the same extent
currently required in the Pinedale
Anticline and Jonah fields pursuant to
the State’s BACT guidelines,
implementing recommendations from
the Upper Green River Basin Air Quality
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Citizens Advisory Task Force, and
adoption of a statewide offset program.
Response: We disagree with this
comment. The commenters did not
provide any evidence of the impact of
VOC emissions on visibility in Class I
areas.
Comment: Wyoming claims that
regulation of drilling rigs is problematic
because drilling rigs are mobile sources
over which states have limited CAA
authority. EPA is not similarly
constrained and may require emissions
reductions from drilling rigs in a FIP.
Replacement of Tier 2 engines with Tier
4 engines on drilling rigs has a cost
effectiveness value as low as $900/ton,
which is very reasonable.
Response: EPA disagrees with this
comment. The costs noted by the
commenter for controls for drill rig
engines are the lower end of the costs
presented by the State. For replacement
of Tier 2 engines with Tier 4 engines,
the State presented costs of $900 to
$2400 per ton of NOX removed, but the
commenter cited only the $900 per ton
figure. To the extent that drill rig
engines could be regulated under the
RHR, this range of costs is not so low
that we are prepared to disapprove the
State’s determination in the reasonable
progress context.
Comment: EPA states it disagrees with
the State’s reasoning for not adopting
reasonable progress controls for the for
oil and gas sources. It is our view that,
having made this finding, it is
inappropriate for EPA to then propose
approval of the State’s control plan, a
plan which would involve no new
controls on the oil and gas sector.
Having found that the State’s RPGs were
not justified, the EPA must put in place
a FIP establishing RPGs for the oil and
gas sector or ask the State to revise its
plan.
There are numerous available means
for controlling NOX from the oil and gas
sector, which is the primary focus that
EPA has. For example, the State has
begun regulating NOX emissions from
drill rigs on the Pinedale Anticline and
Jonah Field. The State has put in place
a number of regulations on those drill
rigs. We believe there is no reason this
could not be extended to other fields in
other portions of the state.
Response: We disagree with this
comment. First, we did not propose
approval of the State’s control plan in
its entirety. Instead, we proposed to
disapprove the State’s reasonable
progress determination for Dave
Johnston Units 1 and 2; we also
proposed to disapprove the State’s
RPGs. We then proposed a FIP for the
RPGs. While we are approving the
State’s reasonable progress
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determination for Dave Johnston Units 1
and 2, we are still finalizing a FIP for
the RPGs, as we have disapproved some
of the State’s BART determinations.
Second, as we stated in our proposal,
although we disagree with the State’s
reasoning with respect to the oil and gas
sector, after considering the costs
presented by the State, we find that they
are not so low that we are prepared to
disapprove the State’s determination in
the reasonable progress context. With
respect to NOX emissions generally from
the oil and gas sector, as discussed
elsewhere, Wyoming applies minor
source BACT to these sources. For drill
rig engines in particular, see our
response above. Finally, with respect to
visibility impacts of NOX emissions
from oil and gas sources on Class I
areas, this comment provided no
particular data. We respond below to
other comments on visibility impacts of
oil and gas sources.
Comment: The State provided sound
reasoning for not adopting reasonable
progress controls for oil and gas sources.
Wyoming is an oil and gas production
state, along with Colorado, North
Dakota, New Mexico, Montana, and
Utah. One of the biggest challenges
faced by these WRAP states has been to
inventory the emissions from this
industry. At the beginning of the
regional haze process, a comprehensive
emission inventory of oil and gas
production operations in the western
region that covered both point and area
sources had not been developed. No
methodology had been developed to
produce an inventory of this scope. The
WRAP oil and gas states collaborated to
develop and implement a uniform
procedure for estimating area source
emissions from oil and gas operations.
WRAP initiated a study to focus on
estimating emissions of pollutants with
the potential to impair visibility near
Class I areas in the West, particularly
NOX emissions.
Developing this inventory has been
one of the most important tasks that
needed to be completed before any of
the western states could begin to look at
imposing controls for improving
visibility. In addition to developing
these critical inventories, the State has
also been very active in identifying and
controlling emissions from the oil and
gas industry. Wyoming has been ahead
of the curve when it comes to
controlling emissions from this industry
to protect health standards. The EPA’s
recently finalized national oil and gas
regulations to reduce air pollutants from
the oil and gas production industry
were patterned in large part after what
Wyoming has been doing since the early
1990’s. Since 2005, the State has been
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spending more time and resources to
study and control emissions from
natural gas production than any other
sector.
When it came time to address
visibility impacts associated with the oil
and gas industry for the RHR, Wyoming
completed the required reasonable
progress analysis. Wyoming also laid
out reasons for why the time was not
right for requiring additional controls on
the industry to reduce visibility
impairment, including lacking the very
critical information to be supplied by
the WRAP inventory study. In spite of
Wyoming’s diligent efforts, EPA
disagrees with the State’s reasoning for
not adopting reasonable progress
controls for the industry during the first
planning period.
EPA has completely misunderstood
the purpose of the collaborative study to
develop and implement a uniform
procedure for estimating area source
emissions from oil and gas operations.
Wyoming could not have developed
such a procedure on their own, and it
continues to make no sense for each
state in the West to develop
independent emission inventories that
cannot be compared to neighboring state
inventories for a regional effort. EPA
should understand this better than any
individual state, since it relies on
consistency in comprehensive national
inventories to develop sound national
rules. While Wyoming waits for the
WRAP inventory study to be completed,
it has not been idle with respect to
developing information on the oil and
gas industry. The State has invested
huge resources in understanding
emissions from this industry and EPA’s
suggestion that the State ‘‘just develop
the information’’ shows a total lack of
understanding of the problem.
EPA’s whole issue is about
substituting its view regarding timing in
place of Wyoming’s reasoned judgment.
Wyoming is hopeful that as it addresses
ozone nonattainment it can also
demonstrate the co-benefits to
improving visibility just as EPA has
done in the East by developing an ozone
control strategy that also demonstrates
adequate visibility improvement.
Wyoming’s effort goes beyond the first
planning period, and is in accordance
with the RHR. Wyoming respectfully
requests that EPA acknowledge that
Wyoming participation in the regional
inventory development process satisfies
reasonable progress for this first
planning period.
Response: We do commend the State
for the work it is doing on developing
more comprehensive information on oil
and gas emissions although we disagree
with this comment. As we stated in our
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proposed notice, we disagree with the
State’s reasoning for not adopting
reasonable progress controls for oil and
gas sources. If the State determined that
additional information on emission data
from oil and gas sources was needed to
potentially control oil and gas sources,
the State should have developed the
information in time for incorporation
into their SIP.
Comment: Wyoming’s booming oil
and gas industry has a significant and
growing impact on visibility in the
State’s national parks and wilderness
areas. Given the close proximity of some
of Wyoming’s largest planned oil and
gas fields to the Bridger and Fitzpatrick
wilderness areas—between just 10 and
200 miles—these magnificent lands in
western Wyoming suffer the greatest
visibility impairment due to oil and gas
activities. The 4,399 additional
approved wells in the Pinedale
Anticline Oil and Gas Exploration and
Development Project alone are projected
to degrade visibility in the Bridger
Wilderness by up to 6.1 deciviews, and
to cause impacts greater than 1.0
deciview on 45 days of each year. This
impact is in addition to the impairment
caused by the existing 1,819 wells in the
Pinedale Anticline area, and the impacts
from the numerous other existing and
planned oil and gas fields in the region.
Wyoming and EPA are obligated to
reduce haze-causing emissions from the
State’s oil and gas industry to achieve
‘‘reasonable progress’’ toward the
national goal of eliminating humancaused visibility impairment in Class I
areas, 42 U.S.C. 7491(b)(2)(B), and doing
so by a target year of 2064, 40 CFR
51.308(d)(1)(i)(B), (ii). See also 42 U.S.C.
7491(b) (requiring ‘‘measures as may be
necessary to make reasonable progress
toward meeting the national [visibility]
goal’’). Under Wyoming’s Regional Haze
SIP, natural visibility conditions would
not be reached in Wyoming’s Bridger
and Fitzpatrick Wilderness Areas until
2165—more than 100 years past the
2064 goal set by EPA. Wyo. 309(g) SIP
at 115. Although EPA’s proposed FIP
includes additional measures that
would hasten visibility improvement,
EPA projects that Wyoming Class I areas
still will not achieve the URP necessary
to restore natural visibility by 2064. 78
FR 34788. Thus, EPA must demonstrate
the reasonableness of its decision not to
require emissions reductions from oil
and gas activities that could make
greater progress toward restoring natural
visibility. 40 CFR 51.308(d)(1)(ii).
Both Wyoming and EPA have failed to
demonstrate that regulating emissions
from Wyoming oil and gas development
activities is not reasonable, in light of
the facts that pollution-control
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technologies are technologically
feasible, cost effective, and would
improve significantly visibility across
several affected Class I areas. EPA
properly ‘‘disagree[s] with the State’s
reasoning for not adopting reasonable
progress controls for oil and gas
sources.’’ 78 FR 34765. Specifically,
EPA rejects the State’s view that it needs
more time to collect information before
it regulates the industry, stating ‘‘[i]f the
State determined that additional
information was needed to potentially
control oil and gas sources, the State
should have developed the
information.’’ Id. EPA also rejects
Wyoming’s claim that it needs up to two
years to develop necessary regulations,
because ‘‘[i]f regulations are needed to
implement reasonable progress controls,
the State must develop them as part of
the regional haze SIP.’’ See also id. at
34764 n.43. The Conservation
Organizations agree that Wyoming is not
excused from regulatory requirements to
commit reasonable emissions reductions
from the oil and gas industry in the
current planning period simply because
Wyoming thinks more information
about oil and gas activity emissions
would be desirable. See 78 FR 34765. As
we pointed out in previous comments,
ample information about oil and gas
industry emissions and their visibility
impacts has already been developed and
published in numerous state and federal
environmental impact statements.
Response: EPA disagrees with the
portions of this comment that take issue
with our proposed action. We
acknowledge the comment’s support for
our statement that Wyoming could not
rely on the lack of data for the State’s
determination for oil and gas sources.
With respect to the projected visibility
impacts of future oil and gas
production, we note that the analysis
cited by the commenter relied on a
background ammonia level of 1 ppb to
determine visibility impacts on the
Bridger Wilderness. Elsewhere, we
explain why we reconsidered use of a
background ammonia level of 2 ppb for
modeling visibility impacts to the
Bridger Wilderness; as a result we
remodeled using both a monitored
monthly varying concentration and an
IWAQM default of 0.5 ppb for
background ammonia. Thus, the
analysis cited by the commenter may
overstate visibility impacts.
Furthermore, modeling of the visibility
impacts alone does not quantify the
potential visibility benefits of the
controls the commenter supports.
The comment cites 40 CFR
51.308(d)(ii), which requires states (or
EPA in this instance) to demonstrate,
when the RPGs fall short of the URP,
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that the RPGs are reasonable and
achieving the URP is unreasonable. As
we stated in our proposal, we found this
to be the case due to the results of the
four-factor analyses along with
emissions from sources outside the
WRAP domain. The commenter does
not take issue with the latter, and we
explain elsewhere that we continue to
think that the controls considered by
Wyoming are not so cost-effective that it
was necessarily unreasonable for
Wyoming to require them.
Comment: Although Wyoming’s
January 2011 SIP identified in particular
a need for the WRAP to complete its
‘‘Phase III’’ inventory of Wyoming oil
and gas emissions before requiring
additional regulations of the industry,
that inventory was completed in
November 2012. WRAP prepared
technical memorandums specific to
three areas in Wyoming—the Powder
River Basin, the Wind River Basin, and
the Greater Green River Basin—
identifying both baseline emissions in
2006 and projected emissions in 2015.
Indeed, WRAP even has completed
‘‘Phase IV’’ of its emissions inventory
project, updating oil and gas industry
baseline emissions as of 2009 for
specific regions, including all three
regions of Wyoming that were evaluated
in Phase III. Thus, Wyoming has no
justification based on incomplete data
for refusing to identify oil and gas
emissions control technology to satisfy
reasonable progress requirements. And
there should be no reason for EPA to
accept Wyoming’s invalid and outdated
claim that more emissions information
is needed when that information was
available for more than six months prior
to EPA’s most recent Wyoming regional
haze proposal.
Response: We disagree with this
comment to the extent that it argues we
should not approve Wyoming’s decision
to not impose controls on oil and gas
sources. We did state in our proposal
that the lack of emissions data was not
an appropriate justification for
Wyoming’s decision to not impose
controls on oil and gas sources. Instead,
we proposed to approve Wyoming’s
decision based on the cost of controls
and on the application of minor source
BACT. The comment does not identify
anything in the November 2012 data
that affects that rationale and does not
explain how emissions data would
change the cost of controls or the
application of the SIP-approved minor
source BACT provisions. Thus the
comment does not give a reason for us
to change our decision.
Comment: While EPA rejects
Wyoming’s rationale for refusing to
limit haze causing pollutants from this
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booming industry, EPA provides
insufficient rationale of its own to
justify the omission. EPA provides two
reasons for proposing to accept the
State’s plan not to require NOX
emissions reductions from Wyoming oil
and gas sources. First, ‘‘the most
reasonable controls are for compressor
engines, which the State already
controls through its minor source BACT
requirements.’’ 78 FR 34765 & n.25
(citing Wyoming Air Quality Standards
and Regulations, Chapter 6, Section 2).
Second, ‘‘while the costs of some
controls are within the range of cost
effectiveness values Wyoming, other
states, and we have considered as
reasonable in the BART context, they
are not so low that we are prepared to
disapprove the State’s conclusion in the
reasonable progress context.’’ Id. at
34765. Neither contention is
supportable.
EPA is wrong that compressor engine
NOX emissions are regulated through
Wyoming’s minor source BACT
requirements. Wyoming’s minor source
BACT guidelines for the oil and gas
industry only regulate VOC and
hazardous air pollutants, not NOX. The
guidelines make no provisions for NOX
controls at all. See State of Wyoming,
Oil and Gas Production Facilities
Chapter 6, Section 2 Permitting
Guidance (presenting controls that
apply to VOC and hazardous air
pollutants, but not NOX).
Moreover, EPA’s singular focus on
compressor engines overlooks the
numerous other opportunities to
significantly reduce haze-causing
emissions from oil and gas operations.
As even Wyoming’s analysis
demonstrates, cost-effective options are
available to achieve high control
efficiency of NOX emissions from drill
rig engines, turbines, and process
heaters. See 78 FR 34764 (Table 26).
Response: We disagree with this
comment. Chapter 6, Sections 2 and 4,
which are approved into the State’s SIP,
both require BACT for new source
compressor engines for regulated
pollutants, which includes NOX and
VOC. These regulatory requirements
should not be confused with the State’s
oil and gas permitting guidance, which
is not part of the SIP. The State
guidance document provides additional
compliance information for select
sources of oil and gas VOC emissions,
such as dehydration units, pumps and
tanks. There are many sources which
are regulated by the State’s SIP and
required to apply controls that are not
included in the oil and gas permitting
guidance.
We also explained the reason we
discussed compressor engines in
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particular: the cost of controls for those
sources was the most reasonable. For
other oil and gas sources, the costs were
generally higher. As we stated in our
proposal, those costs were not so low
that EPA could find it necessarily
unreasonable for the State to not have
adopted them. The comment gives us no
reason to think otherwise.
Comment: EPA’s justification that the
costs of available controls are
reasonable, but not so low that EPA is
willing to require them, is both arbitrary
and factually flawed. See 78 FR 34765
(‘‘the costs of some controls are within
the range of cost effectiveness values
Wyoming, other states, and we have
considered as reasonable in the BART
context’’). EPA’s justification is arbitrary
because it has not identified any
objective threshold or rationale for
reaching the determination that costs,
although low, are still too high to justify
modifying Wyoming’s SIP
determination.
Indeed, EPA rejected Wyoming’s
determination not to require reasonable
progress controls for Dave Johnston
Units 1 and 2, where the controls would
cost approximately $1,000/ton of NOX
removed. See id. at 34788 (‘‘Given
predicted visibility improvement of
approximately 0.30 deciviews per unit
at the most impacted Class I area and
the fact that Wyoming’s RPGs will not
meet the URP, we find that it was
unreasonable for the State to reject these
very inexpensive controls.’’). EPA’s
statement that control technologies with
similar—and even lower—costs were
not justified for the oil and gas industry
cannot be squared with this
determination for Dave Johnston Units 1
and 2. See id. at 34765. As shown in
Table 26 (of the proposed FIP),
emissions controls for compressor
engines are available in the $16 to
$1,200/ton range. Id. at 34764.
Enhanced NOX-control technologies for
drill rigs have cost-effectiveness values
of $900 to $1,000/ton. Id.
Controls for NOX emissions from
turbines are very cost effective at around
$560/ton. Id. All of these costs are at or
below the costs that were deemed ‘‘very
reasonable’’ at the Dave Johnston power
plant and which led to EPA rejecting the
State’s reasonable progress control
proposal. If finalized, EPA’s contrary
proposal for the Wyoming oil and gas
industry would be arbitrary.
Response: EPA disagrees with this
comment. The comparison with the
costs of controls at Dave Johnston Units
1 and 2 is not apropos. First, as
explained elsewhere, certain oil and gas
sources are subject to the State’s SIPapproved construction permit program,
including the requirement for minor
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source BACT. On the other hand, as
explained below in response to
PacifiCorp’s comments, PacifiCorp did
not identify (nor is EPA aware of) any
NOX control measures for Dave Johnston
Units 1 and 2. Second, we did not
propose to reject the State’s
determination for these units solely on
the basis of the cost-effectiveness of
controls. In addition, the State relied on
impermissible factors to disregard the
results of its own four-factor analysis.
Third, to assist in determining whether
the state’s determination for Dave
Johnston Units 1 and 2 was reasonable
or not, we have quantified the visibility
benefits of controls and decided that the
State’s determination was not so
unreasonable that we were prepared to
disapprove it. Neither the commenter
nor EPA has equivalent data for the oil
and gas sources that the commenter
mentions. The visibility benefits of the
commenter’s suggested controls would
of course vary considerably depending
on the location of the source and other
factors, and the data the commenter
cites elsewhere regarding the bulk
visibility impacts of oil and gas
development do not address visibility
benefits. Thus, the comparison with
Dave Johnston gives no reason to change
our decision. Finally, the RHR does not
require EPA to establish a hard-and-fast
dollar per ton threshold or other
numeric criteria for determining when a
State’s decision to not impose controls
on reasonable progress sources is
unreasonable; rather all four factors are
to be considered under the reasonable
progress provisions of the RHR.
Comment: Control technologies to
reduce oil and gas industry NOX
emissions are inexpensive and justified.
Wyoming did not identify the cost of
available controls as an impediment to
their implementation, and Wyoming’s
own analysis demonstrated that costeffective controls to reduce oil and gas
industry emissions are available. See
Wyo. 309(g) SIP at 123–26. In addition
to Wyoming’s generic analysis, the
Conservation Organizations have
identified available control technology.
For example, the Bureau of Land
Management (BLM) recommended basic
pollution-reduction strategies such as
replacing internal combustion engines
for compressors with gas turbines,
installing SCR on drilling rig engines,
using electric or natural gas-powered
drilling rigs, and centralizing
production facilities to reduce truck
traffic. The cost-effectiveness of such
technologies is a reason for requiring
them as reasonable progress measures;
costs are not a basis for allowing
Wyoming to avoid requirements to
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reduce the large impact of the State’s oil
and gas industry on Class I-area
visibility.
Response: EPA disagrees with this
comment. First, the commenter
incorrectly suggests that a ‘‘generic’’
analysis, rather than a source-specific
analysis, of the cost of controls for oil
and gas sources violates the RHR. In the
reasonable progress context, the cost-ofcompliance factor can be interpreted to
encompass either the cost of compliance
for individual sources or the cost of
compliance for source categories. The
language of 40 CFR 51.308(d)(1)(i)(A),
cited by the commenter, does not
explicitly require a source-specific
analysis of the costs of compliance,
contrary to the commenter’s assertion.
With respect to the control measures
identified by BLM and referred to by the
commenter, neither the comment, nor
the letter cited in the comment, nor the
records of decisions by the BLM cited
by the letter, provide any data on the
cost-effectiveness of these measures.
The comment has no basis to describe
the control measures identified by BLM
as cost-effective.
Comment: When a SIP fails to
establish an emissions reduction
strategy that would achieve natural
visibility conditions by 2064, as is the
case in Wyoming, the state must
demonstrate that the underlying
‘‘uniform rate of progress’’ is ‘‘not
reasonable[,] and that the progress goal
adopted by the State is reasonable.’’ 40
CFR 51.308(d)(1)(ii); see also EPA,
Guidance for Setting Reasonable
Progress Goals Under the Regional Haze
Program, at 2–3 (June 1, 2007)
(demonstration should ‘‘identify and
analyze the measures aimed at
achieving the uniform rate of progress
and . . . determine whether these
measures are reasonable’’). EPA
proposes RPGs that leave visibility
impaired in Wyoming’s affected Class I
areas well beyond the 2064 goal set by
EPA. See 78 FR 34788. In light of EPA’s
rejection of every one of Wyoming’s
justifications for its conclusion that
reasonable progress controls on the oil
and gas industry are not reasonable, and
EPA’s lack of any valid rationale of its
own to conclude that such measures are
not reasonable, the failure to adopt any
measures to reduce haze-causing
emissions from the oil and gas industry
cannot be supported and must be
changed in the final rule.
Response: EPA disagrees with this
comment. In our proposal we
specifically stated our rationale for
agreeing with Wyoming’s determination
to not impose controls on oil and gas
sources during this planning period. We
respond elsewhere to the commenter’s
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disagreement with that rationale.
Because we are disapproving the State’s
RPGs, as part of our FIP we are
imposing RPGs that are consistent with
the controls in our FIP and the controls
that we are approving in the State’s SIP.
We stated in our proposal that it was
reasonable for the RPGs to fall short of
the URP based not only on our
consideration of the four statutory
reasonable progress factors, but also
based on emissions from sources
outside the WRAP domain, which the
commenter does not take issue with.
Comment: EPA proposes to approve
Wyoming’s reasonable progress
determinations for oil and gas sources.
78 FR 34765. However, EPA states that
it ‘‘disagree[s] with the State’s reasoning
for not adopting reasonable progress
controls for oil and gas sources.’’ Id.
Wyoming explained in its SIP that it
required additional information before it
can determine whether and to what
extent additional controls are necessary
for oil and gas sources. Id. EPA thinks
Wyoming should have obtained the
additional information before
submitting its SIP, though, EPA does not
hold itself to this same standard.
Nonetheless, EPA has previously
recognized Wyoming’s expertise and
leadership in regulating the air quality
impacts of oil and gas development. 76
FR 52738, 52757 (Aug. 23, 2011). In
light of Wyoming’s leadership in
regulating air pollution from oil and gas
development, EPA should approve
Wyoming’s reasonable progress
determination for oil and gas sources.
Response: EPA disagrees with this
comment. We are approving Wyoming’s
reasonable progress determination for
oil and gas sources, although not on the
State’s basis. The notice cited in the
comment relates to EPA’s development
of new source performance standards
for oil and gas sources, which is not
relevant to this action. As we explained
in our proposal and elsewhere in these
responses, the RHR sets certain
requirements for reasonable progress for
the first planning period and does not
provide for deferring those requirements
to later planning periods; thus, the
State’s basis for its reasonable progress
determination for oil and gas sources is
invalid. Finally, while we did not re-run
the WRAP modeling to quantify our
RPGs, the State did not modify its RPGs
or re-run the WRAP modeling to reflect
the controls the State selected.
Comment: We received numerous
comments urging EPA to require
pollution controls on the oil and gas
industry.
Response: There are a number of
provisions in the CAA that potentially
apply to oil and gas sources. With
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respect to the requirements of the RHR
for those sources, we have evaluated
Wyoming’s submittal and we are
approving it.
b. Dave Johnston Units 1 and 2
Comment: Wyoming did not evaluate
the effectiveness of the LNB+OFA+SCR
option. Instead, Wyoming assumed
addition of SCR to these currently
uncontrolled EGUs would only reduce
NOX emissions by 79% down to 0.12 lb/
MMBtu on an annual average basis,
although it is generally assumed that
SCR can reduce NOX emissions by 90%
or down to 0.05 lb/MMBtu (or lower).
Wyoming has not provided any
documentation or justification to
support the higher emission rates used
in its analyses. Such an approach at
Johnston adversely biases the costbenefit analysis and is inconsistent with
other EPA analyses.
Response: The commenter has
incorrectly assumed that a 90% control
efficiency can be achieved in all SCR
applications regardless of the input NOX
emission rate or other parameters. In
addition, we note that the emission rate
analyzed by Wyoming, 0.07 lb/MMBtu,
was on a 30-day rolling average basis,
not an annual basis. Regardless, we
agree that SCR can in most cases
achieve a performance rate of 0.05 lb/
MMBtu on an annual basis. (See section
IV.C.4 of this rulemaking for more
information on the control effectiveness
of SCR.) We have revised the SCR costs
for Dave Johnston Units 1 and 2
accordingly. However, as explained
elsewhere, the revised costs for SCR
have not led us to change our
determination that the State was
reasonable in not selecting SCR for
Units 1 and 2.
Comment: Wyoming has assumed that
Dave Johnston Unit 1 and Unit 2
emitted at 0.57 lb/MMBtu on an annual
basis and used this as the baseline
condition from which to calculate the
control efficiency it used for each
control option. However, our review of
CAMD data back to 2000 shows that the
highest annual NOX emission rate for
Unit 1 was 0.474 lb/MMBtu (2002) and
0.460 lb/MMBtu for Unit 2 (2006). For
the 2001–2003 baseline period, annual
NOX emissions were 0.46 and 0.44 lb/
MMBtu for Johnston Unit 1 and Unit 2,
respectively. Thus, Wyoming’s proposal
to reduce NOX to 0.20 lb/MMBtu with
LNB+OFA represents a 56% reduction
instead of 65% assumed by Wyoming.
Response: In our revised cost analysis,
we used baseline emissions for Dave
Johnston Units 1 and 2 that reflect
annual average emissions between 2001
and 2003, as found in the CAMD
emissions system. These baseline rates
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are 0.45 lb/MMbtu and 0.41 lb/MMBtu,
respectively. This corresponds to a
56.0% and 54.6% reduction,
respectively.238 Therefore, our revised
cost analysis has addressed the concern
raised by the commenter. As explained
elsewhere, our revised costs have been
taken into account, along with our
revised visibility modeling, in our
decision to approve the State’s
determination to not impose controls at
Units 1 and 2.
Comment: The Conservation
Organizations agree with EPA that
reasonable progress controls for NOX
emissions are needed for Dave Johnston
Units 1 and 2. EPA correctly found that
it was unreasonable for Wyoming to
reject cost effective NOX controls that
would improve visibility. EPA proposes
to require only LNBs/OFA to achieve a
NOX emission limit of 0.20 lb/MMBtu
(30-day rolling average). While we
commend EPA for proposing a FIP to
reduce NOX emissions from Dave
Johnston Units 1 and 2, we urge EPA to
require SCR plus LNBs/OFA to meet a
NOX emission limit of 0.05 lb/MMBtu to
achieve reasonable progress. Although
EPA concluded that the cost of SCR is
not justified by the projected visibility
improvement, EPA’s analysis
unreasonably assumed that SCR would
only achieve a NOX emission rate of
0.12 lb/MMBtu, even though an
emission rate of 0.05 lb/MMBtu is
readily achievable. Correcting for this
error, it appears that SCR at Dave
Johnston Units 1 and 2 is very cost
effective at $2,001 and $1,987/ton of
NOX removed, respectively.
Accordingly, EPA should reconsider
requiring SCR at Dave Johnston Units 1
and 2 to meet reasonable progress
requirements.
Response: As discussed in our
proposed rulemaking, we have revised
the SCR cost analysis for Dave Johnston
Units 1 and 2 to reflect the installation
of LNB and OFA. However, our revised
cost effectiveness values of $3,496/ton
and $3,672/ton, respectively, are much
higher than those suggested by the
commenter. We also note that the
incremental costs for this option are
high, at $9,798 and $9,588 per ton,
respectively. In light of this, and our
revised modeling results, we do not find
it unreasonable for the State to not have
imposed SCR on these units.
Comment: EPA’s conclusion that the
addition of SCR is not justified due to
the ‘‘small incremental visibility
improvement’’ is based upon a flawed
visibility analysis that over-values the
addition of LNB + OFA and undervalues the addition of SCR.
238 Staudt
memo, Tables 2 and 3.
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Furthermore, the degree of visibility
improvement is not one of the four
statutory factors to be considered under
the reasonable progress provisions of
the RHR. Incremental visibility
improvement is not mentioned
anywhere in the reasonable progress
provisions or BART Guidelines and EPA
cannot create a new criterion for the
sole purpose of eliminating a control
option that is reasonably cost-effective
and would yield a significant visibility
improvement.
Response: As discussed elsewhere in
this rulemaking, we have corrected the
modeling analysis for Dave Johnston
Units 1 and 2, and the commenter’s
concerns regarding our methodology
have been addressed. Our revised
modeling analysis shows that the
visibility improvement associated with
SCR with LNB and OFA at Units 1 and
2 is 0.18 deciviews and 0.18 deciviews,
respectively. The visibility
improvement associated with LNB and
OFA is 0.12 deciviews and 0.11
deciviews, respectively. We continue to
find that the additional visibility
improvement is not significant enough
to warrant selection of SCR with LNB
and OFA for these reasonable progress
sources. As discussed earlier, we also
find that the visibility improvement
from LNBs and OFA does not justify us
requiring reasonable progress controls
on these two units. While it is true that
incremental visibility improvement is
not among the four statutory reasonable
progress factors, the RHR does not
prohibit EPA from assessing visibility
improvement, in addition to the four
statutory reasonable progress factors,
when considering controls at potentially
affected sources. We did not create a
new criterion for the sole purpose of
eliminating SCR at Dave Johnston Units
1 and 2; instead, we think it appropriate
to consider visibility improvement
when assessing control options for
reasonable progress, especially when
taking into account the purposes of the
RHR. In comparing control options and
selecting one, it is appropriate to
compare the visibility improvement
(that is, to compute the incremental
visibility improvement) for each option.
Comment: EPA is proposing that the
FIP NOX BART for Dave Johnston Units
1 and 2 is LNBs with OFA at an
emission limit of 0.22 lb/MMBtu (30day rolling average). EPA provided no
reason for rejecting addition of SCR
even though: (1) Cost/ton was $3,300–
$3,400, which is less than the $3,900/
ton accepted at Laramie River Unit 3; (2)
Visibility at the most-impacted Class I
area would improve by more than 0.4
deciview (which is greater than the 0.3
deciview improvement for EPA’s
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proposal; (3) Cumulative visibility
improvement would exceed 0.6
deciviews (versus EPA’s proposed 0.43
deciview improvement for Dave
Johnston Unit 2 at Wind Cave and
Badlands); (4) Cost-effectiveness is $15
million/deciview at Wind Cave (versus
$27,798,246/deciview at Badlands due
to application of SCR to Laramie River
Unit 3); (5) Cumulative costeffectiveness is less than $10 million/
deciview (versus $10,140,825/
cumulative deciview due to application
of SCR to Laramie River Unit 2.)
We believe that SCR is Reasonable
Progress for Dave Johnston Units 1 and
2. Under the EPA proposal, Dave
Johnston Units 1 and 2 would each
contribute over 0.9 deciview
impairment at Wind Cave National Park
(and 0.7 deciviews at Badlands National
Park). With the addition of SCR,
impairment would drop to less than 0.5
deciviews for each unit.
Response: We disagree with this
comment. We have responded in detail
to the use of a $/deciview metric in
section V.D.1.b of this final rulemaking
action. In addition, as stated above, our
revised modeling analysis shows that
the visibility improvement associated
with SCR with LNB and OFA is 0.18
deciviews and 0.18 deciviews,
respectively. By contrast, the visibility
improvement associated with LNB and
OFA, is 0.12 deciviews and 0.11
deciviews, respectively. We continue to
find that the additional visibility
improvement is not significant enough
to warrant selection of SCR with LNB
and OFA for these reasonable progress
sources, and as discussed earlier in our
response to comments, we do not find
the visibility improvement, when
considered with the other reasonable
progress factors, from LNBs and OFA
warrants the implementation of
reasonable progress controls. In
addition, as we discuss above, the
revised incremental costs for SCR that
we present above are sufficiently high
for us to conclude that it is reasonable
to not impose SCR on Dave Johnston
Units 1 and 2.
Comment: EPA acknowledged that,
for a reasonable progress analysis, only
four factors must be analyzed. Indeed,
the CAA clearly requires only four
factors be analyzed. 42 U.S.C.
7491(g)(1). EPA employed the fourfactor reasonable progress analysis for
the other two Wyoming reasonable
progress sources: oil and gas sources
and the Mountain Cement Company
plant. EPA has approved other regional
haze SIPs where the state employed this
same four-factor analysis, including
Nevada. For both the oil and gas sources
and the Mountain Cement Company
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plant, EPA disagreed with Wyoming’s
reasonable progress analysis and found
‘‘cost effective’’ NOX controls could be
employed, but EPA did not require
those NOX controls because the costs
were ‘‘not so low that we are prepared
to disapprove the State’s conclusion in
the reasonable progress context.’’ If EPA
found the NOX controls ‘‘cost effective’’,
then PacifiCorp is unclear what
additional cost analysis was performed,
or what the statutory or regulatory basis
for EPA’s additional cost analysis may
be. EPA does not differentiate
PacifiCorp’s Dave Johnston Units 1 and
2 from the oil and gas sources or the
Mountain Cement Company plant.
Also, EPA has approved other
reasonable progress SIPs where the state
is not meeting the URP, but has
determined that no reasonable progress
controls are required for the initial
planning period. (See 77 FR 30248,
30256–30257; SIP Approval for Idaho).
Here, EPA admitted that Wyoming
‘‘provided a four factor analyses that
adequately evaluated the required
factors’’ for Dave Johnston Units 1 and
2, but then arbitrarily concluded ‘‘it is
also appropriate for this facility to
consider a fifth factor for evaluating
potential reasonable progress control
options—the degree of visibility
improvement that may reasonably be
anticipated from the use of reasonable
progress controls.’’
EPA justified its decision by citing to
EPA guidance on states setting
reasonable progress goals. However, the
referenced guidance does not support
EPA’s position for several reasons:
• The guidance concedes it is
‘‘merely guidance and that States or the
. . . [EPA] may elect to follow or
deviate from this guidance, as
appropriate.’’ EPA cannot find
Wyoming acted ‘‘unreasonably’’ when it
chose not to apply discretionary
guidance.
• The guidance identifies several
factors that EPA did not include in its
proposed regional haze FIP, such as the
‘‘control measures and associated
emission reductions that are expected to
result from compliance with existing
rules.’’ EPA cannot criticize Wyoming
for not following the guidance when
EPA itself chose not to apply part of the
same guidance in the EPA regional haze
FIP.
• The guidance suggests that air
quality models be used to estimate ‘‘the
improvement in visibility that would
result from the implementation of the
control measures you have found to be
reasonable and compare this to the
uniform rate of progress.’’ Here, EPA has
no ‘‘modeling results’’ demonstrating
the alleged improvement in visibility
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from the suggested NOX controls and
the impact on the URP.
• The States, not EPA, are to
determine the ‘‘reasonableness’’ of RPGs
and are given flexibility to do so.
• The guidance clearly indicates that
a state must support its RPGs ‘‘based on
the statutory factors,’’ which EPA
admits Wyoming did.
• Finally, the guidance explains that
no additional reasonable progress
controls may be needed for the first
planning period.
Response: EPA disagrees with this
comment. With respect to the
reasonable progress determination for
the Mountain Cement facility, the cost
effectiveness of potential controls is
generally higher than the controls we
proposed for Dave Johnston Units 1 and
2. As we stated in our proposal,
although the costs for potential controls
for the Mountain Cement facility might
be considered reasonable in the BART
context, in the reasonable progress
context those costs were not so low that
we were prepared to disapprove the
State’s determination to not impose
controls. That was not the case for Dave
Johnston Units 1 and 2, for which
combustion controls were significantly
more cost-effective. Similar reasoning
applies to the cost-effectiveness of
controls for the oil and gas sources; in
addition, as we noted in the proposal,
Wyoming generally applies minor
source BACT to these sources.
As a result, EPA determined that we
should perform visibility modeling to
assess the visibility benefits of controls
on Dave Johnston Units 1 and 2. As
explained elsewhere, we considered it
appropriate to assess, in addition to the
four statutory reasonable progress
factors, the visibility improvement from
potential controls at these units,
particularly in light of the purposes of
the RHR. In this instance, the revised
visibility modeling has confirmed that
the State’s decision to not impose
controls on Dave Johnston Units 1 and
2 (although not the State’s rationale)
was not so unreasonable that EPA is
compelled to disapprove it.
EPA also disagrees that EPA’s
proposal was inconsistent with the cited
notice proposing action on the Idaho
Regional Haze SIP. In that notice, EPA
stated, ‘‘EPA agrees with Idaho’s
conclusion that additional controls of
non-BART point sources for reasonable
progress purposes are not reasonable at
this time, because even though there are
cost effective controls identified,
visibility improvement is anticipated to
be relatively small.’’ (77 FR 30248,
30256, May 22, 2012) (emphasis added).
To derive that conclusion, EPA
examined the modeled visibility
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impacts for the BART eligible sources
and noted that, in Idaho’s case, the
sources with a Q/d of less than 26 had
visibility impacts of less than 0.5
deciviews. EPA conservatively inferred
from this that other potentially affected
sources in Idaho with a Q/d of less than
20 would likely also have visibility
impacts of less than 0.5 deciviews. In
contrast, our original proposal showed
modeled benefits at each unit of 0.3
deciviews from combustion controls. As
a result, we reject the comparison with
the notice proposing action on the Idaho
Regional Haze SIP. Nonetheless, based
on our revised modeling we have
reconsidered our proposed
determination to require LNBs and OFA
on these two units, and now do not find
the State’s decision to not impose
controls to be unreasonable.
Furthermore, we are not disapproving
the State’s determination of which
sources should be considered
potentially affected sources. Wyoming
reasonably used a Q/d threshold of 10
for determining the set of potentially
affected sources, and the State selected
(among others) Dave Johnston Units 1
and 2. That Idaho used a different
threshold does not show that
Wyoming’s choice was unreasonable.
However, even if EPA in the first
instance was selecting potentially
affected sources, we might also consider
it reasonable to select Dave Johnston 1
and 2 based on a Q/d threshold.
We disagree that we cited our
reasonable progress guidance as part or
whole of our basis for proposing to
disapprove the State’s reasonable
progress determination for Dave
Johnston Units 1 and 2. Instead, we
briefly cited the guidance for the
unremarkable proposition that the State
must at a minimum consider the four
statutory reasonable progress factors but
could also take into account other
relevant factors. Our proposed
disapproval was not based on that
proposition, but was based on the
State’s inadequately supported
determination to not impose controls,
which relied on impermissible factors.
Although the commenter argues that it
is the State, and not EPA, that should
determine reasonable progress, as
explained above we are required to
evaluate the State’s reasonable progress
determinations. 40 CFR 51.308(d)(1)(iii).
We disagree with the commenter’s
other statements regarding the guidance.
While the State did assess the four
statutory reasonable progress factors for
Dave Johnston Units 1 and 2, the
guidance does not suggest that a state
may ignore the results of that
assessment for impermissible reasons
such as a claimed lack of authority. The
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guidance also does not suggest that a
state may per se choose to impose no
reasonable progress controls regardless
of the state’s assessment of the four
statutory factors.
Guidance aside, both the Act and the
RHR explicitly require the state to
consider the four factors for potentially
affected sources. CAA section
169A(g)(1) (‘‘shall be taken into
consideration’’); 40 CFR
51.308(d)(1)(i)(A). Assessing the four
factors but ignoring the results of that
assessment for invalid reasons such as
lack of authority to impose controls
does not amount to considering the
factors and violates the explicit
requirements of the Act and the RHR.
With respect to control measures
expected to result from compliance with
existing rules, the commenter did not
identify any such NOX control measures
for Dave Johnston Units 1 and 2, nor are
we aware of any. Finally, we did
independently run CALPUFF to model
the visibility improvement from
potential controls at Dave Johnston
Units 1 and 2 and it is part of the basis
for our final decision.
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F. General Comments
1. Replacement of FIP Elements With
SIP
Comment: EPA has proposed to
disapprove the monitoring,
recordkeeping, reporting, and RAVI
portions of Wyoming’s SIP. 78 FR
34788. Wyoming acknowledges these
deficiencies in its SIP and commits to
making the necessary revisions.
However, Wyoming will revise its SIP in
a manner that comports with statutory
and regulatory processes. Unlike EPA,
Wyoming will not shortcut legal
processes designed to ensure FLM
consultation and public participation to
meet an arbitrary deadline EPA has
established with special interest groups
in litigation to which Wyoming was not
a party. Such arbitrary deadlines defeat
the cooperative federalism Congress
intended to guide CAA implementation
by needlessly expediting the process,
tying EPA’s hands, and precluding the
State from an opportunity to revise its
SIP. In this context, EPA’s promise—to
‘‘propose approval of a SIP revision as
expeditiously as practicable if the State
submits such a revision and the revision
matches the terms of our proposed FIP,’’
id. 34738—rings hollow.
Response: We appreciated the State’s
willingness to make the SIP revisions
necessary to correct the deficiencies
with the monitoring, recordkeeping,
reporting, and RAVI requirements. Once
EPA receives the SIP revisions from the
State, EPA will work as expeditiously as
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practicable to review such revisions and
approve the State’s revisions if they
meet the terms of our FIP. We have
responded to other comments elsewhere
in this document.
2. Public Comment
Comment: DEQ and Governor Mead
requested that EPA defer its hearing
until sixty days after the date EPA first
released its proposal, with an additional
thirty days of comment after the
hearing. See, e.g., Letter from Todd
Parfitt, Director, DEQ, to Shaun
McGrath, Region 8 Administrator, EPA
(June 14, 2013). Although EPA agreed to
hold two additional public hearings and
provide an additional thirty days for
public comment, EPA did not provide
the time for public participation that
Wyoming requested, evidently because
EPA wanted to meet the deadline for
final action it established with the
special interest groups. Thus, while EPA
did not hesitate to extend that deadline
on multiple occasions when it
benefitted EPA and the special interest
groups, EPA refused to provide the
additional time Wyoming requested for
the benefit of the State.
We also received comments from
other parties that we should extend the
public comment period so that there is
more time to review and comment on
our action. Some commenters
specifically requested a 60-day
extension of the comment period. One
commenter noted that if the driving
force for the short timeframe in this
instance is a consent decree to which
the EPA is a party, that no agreement
between an agency and any interested
party, whether as part of litigation or
not, should or can modify requirements
of law for a meaningful opportunity for
public comment.
Response: EPA took several steps to
provide the opportunity for meaningful
public comment. In addition to the
initial 60-day public comment period,
we extended the public comment period
from August 9, 2013, until August 26,
2013. In doing so, we took into
consideration how an extension might
affect our ability to consider comments
received on the proposed action and
still comply with the terms of the
consent decree deadline,239 which at the
time required our final action signed by
the Administrator on or before
November 21, 2013. Additionally, we
could not extend the comment period
any further and still have time to
respond to the immense amount of
public comments we anticipated
receiving. As the commenter notes, EPA
239 WildEarth Guardians v. McCarthy, Case No.
1:11–cv–0001–CJA–MEH.
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5209
also added two public hearings and we
received substantial comments at these
additional hearings. We find that the
comment period provided for the
Wyoming Regional Haze SIP and FIP
exceeds CAA requirements and is
reasonable and consistent with what the
Agency has provided on other FIP and
SIP actions. For example, EPA provided
a 60-day comment period for both the
Montana and North Dakota regional
haze actions (see 77 FR 23988 and 76 FR
58570, respectively.) In addition, in our
first proposal on Wyoming regional haze
(77 FR 33022), we provided a 60-day
comment period with no objections
from interested parties.
Finally, the State and impacted
sources have had many years to prepare
and submit an approvable SIP to EPA.
As detailed in the Docket for this action,
the State received numerous detailed
comment letters from EPA on many
issues and also participated in meetings
with EPA. Indeed, the fact that the State
was able to prepare an extensive 33page document and provide extensive
comments at the various public
hearings, all within the allotted time
period, supports EPA’s contention that
the 77-day time period for this proposed
rulemaking was reasonable.240
3. Economic Concerns
Comment: We received numerous
comments that the FIP will cost
anywhere from an additional $300
million to $1 billion more than the
State’s SIP, but provide no perceptible
improvement in visibility when
compared with the SIP. We received
numerous comments that EPA’s FIP
would lead to higher electricity costs to
consumers and job losses at a time when
the economy and people cannot afford
an additional burden.
Response: We disagree with these
comments. We have addressed the issue
of perceptible visibility improvement in
section V.C.5 of this final rulemaking. In
addition, it is not EPA’s intention to
endanger the economic viability of or to
place an undue burden on PacifiCorp or
Basin Electric’s customers. EPA has
considered the comments on these
issues very carefully. Regarding the
legal basis for our decision, neither the
CAA nor the RHR requires states or EPA
to consider the affordability of controls
or ratepayer impacts as part of a BART
analysis. Rather, the CAA and RHR
require consideration of the following
factors, which as detailed elsewhere in
240 In fact, the State received the proposed notice
on May 28, 2013, two business days after the
proposal was signed, and the proposed notice was
posted on the Region’s Internet site on May 28,
2013, well in advance of the Federal Register
publication on June 10, 2013.
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our notice, we have fully considered:
‘‘The costs of compliance, the energy
and non-air quality environmental
impacts of compliance, any existing
pollution control technology in use at
the source, the remaining useful life of
the source, and the degree of
improvement in visibility which may
reasonably be anticipated to result from
the use of such technology.’’
Comment: One commenter noted that
visitors to Wyoming’s parks notice
when the air is dirty, which can have a
direct impact on tourism, the second
largest business in the State. According
to Wyoming’s Office of Tourism, the
travel and tourism industry in Wyoming
creates 30,000 jobs and generates $730
million in employment earnings and
$2.8 billion in travel expenditures
annually. Over 3.5 million people visit
Yellowstone National Park each year.
The Commenter also indicated that the
proposed plan will also reduce health
care costs in the State. Combined, coal
plants in Wyoming emit over 60,000
tons of NOX pollution and almost
65,000 tons of SO2 pollution annually.
The Clean Air Task Force estimates that
coal plant pollution in the State results
in over $850 million in preventable
health care costs.
Response: We acknowledge the
commenter’s points.
Comment: We received a comment
that EPA failed to calculate the costs of
the proposed rule that will be passed on
to residential and business customers.
Response: Explained elsewhere in this
document, we have taken these costs
into consideration.
Comment: We received numerous
comments that EPA’s action could have
the potential to shift the energy balance
in favor of gas, rather than coal, and that
this shift may force utilities to convert
their power plants from coal to natural
gas. Commenters expressed particular
concern over the potential conversion of
Naughton Unit 3, and possibly
Naughton Units 1 and 2. Commenters
expressed concern over the potential
impacts natural gas conversion could
have on local economies.
Response: As stated above, the CAA
and RHR require consideration of the
five statutory factors. Based on our
consideration of these factors, EPA
determined the appropriate emission
limit for BART for each unit. Sources
have the choice of how to meet that
limit, including conversion to natural
gas. EPA’s action does not require any
source to convert to natural gas, as all
of the requirements in our FIP can be
met with combustion and postcombustion control technology.
Comment: One commenter stated that
coal-fired plants in Wyoming have
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installed over one billion dollars in
additional air quality controls and that,
according to EPA standards, Wyoming
has better visibility than virtually any
other state in the country. Therefore, it
seems unreasonable, illogical and,
frankly, irrational that the EPA would
demand Wyoming businesses and
homeowners foot the bill for another
one billion dollars in emission controls
that have little probability of improving
the quality of lives or the livelihoods of
our citizens and, in fact, has a great
potential to harm our people and our
state.
Response: EPA disagrees with this
comment. EPA carefully considered the
five statutory factors and determined
that there are additional, cost-effective
controls that will result in significant
visibility improvement in Wyoming’s
Class I areas, and that these controls
represent BART.
Comment: One commenter was
concerned that the investments
mandated under the FIP will have
significant adverse impacts on the
quality and reliability of service
provided to Wyoming ratepayers. The
SIP is a well vetted plan by the State
and its stakeholders that, in association
with other regulatory requirements such
as the construction authority process,
assures that Wyoming utilities will be
able to comply with its requirements
with the least amount of impact to
customers. The FIP, on the other hand,
with its more stringent control
requirements and accelerated
compliance deadlines, will assure not
only that compliance is needlessly
expensive, but that it is also rushed, that
scheduled outages cannot be timed to
minimize the cost of replacement
power, and that third party vendors will
have free reign in determining how
much a particular project costs. To the
extent that schedules cannot be met,
non-compliant plants will be forced out
of service until the work is done. Such
outages will necessitate the purchase of
replacement power in the market and
will result in diminishing system
reserves, all of which will jeopardize
system reliability and increase costs for
ratepayers.
Response: We appreciate the
commenter’s concerns, but note that the
commenter has provided no data to
support these assertions.
Comment: The companies working
with Wyoming have scheduled
shutdown and installation on a
schedule that will allow them to
maintain service to their customers. The
new timeline demanded in the reproposal would threaten both service
interruptions and an increased risk of
having to spot purchase energy which
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would be an additional increase of costs
to residential, business, manufacturing,
and agricultural customers.
Response: We appreciate the
commenter’s concerns, but note that the
commenter has provided no data to
support these assertions. Additionally,
CAA section 169A(b)(2)(A) requires
subject-to-BART sources to install BART
and comply with any applicable
emission limits ‘‘as expeditiously as
practicable.’’ The Act defines this term
to mean ‘‘as expeditiously as practicable
but in no event later than five years after
. . . the date of promulgation.’’ CAA
section 169A(g)(4). Consequently, the
final rule appropriately provides that
the BART units must comply with the
emission limits as expeditiously as
practicable but in no event later than
five years after the date of promulgation
of the final rulemaking.
4. National Ambient Air Quality
Standards (NAAQS)
Comment: The EPA is duty-bound to
ensure that the proposed SIP does not
interfere with attainment and
maintenance of the NAAQS, in
accordance with section 110(l) of the
CAA. Thus, the EPA must ensure that
the proposed SIP and the proposed FIP
adequately limit air pollution in order to
safeguard public health.
In this case, we are concerned that in
proposing to approve portions of
Wyoming’s regional haze plan, the EPA
has not demonstrated that the proposal
adequately safeguards the 2008 8-hour
ozone NAAQS (see 40 CFR 50.15), the
newly promulgated 1-hour nitrogen
dioxide (‘‘NO2’’) NAAQS (see 40 CFR
50.11(b)), the newly promulgated 1-hour
SO2 NAAQS (see 40 CFR 50.17), the
2006 24-hour PM2.5 NAAQS (see 40 CFR
50.13), and the 2012 annual PM2.5
NAAQS (see 78 FR 3086 (Jan. 15, 2013)).
We are particularly concerned that the
EPA overlooked its 110(l) obligations
under the CAA given that, although the
Proposed Rule may lead to emission
reductions, no analysis or assessment
has been prepared to demonstrate that
even after these emission reductions,
the recently promulgated NAAQS will
be met. In this case, we are particularly
concerned that the recently promulgated
1-hour NO2 and SO2 NAAQS could be
jeopardized, as well as the recently
promulgated 2012 PM2.5 annual
NAAQS. Indeed, many, if not most, of
the proposed emission rates are based
on 30-day rolling averages. There is no
indication that meeting emission rates
on a 30-day rolling average will ensure
that 1-hour NAAQS will be sufficiently
protected. Indeed, a source could
comply with a 30-day rolling average
limit, yet still emit enough pollution on
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an hourly basis to cause or contribute to
violations of the NAAQS, thereby
interfering with attainment or
maintenance. Further, there has been no
analysis at all as to whether the recently
promulgated revisions to the annual
PM2.5 NAAQS will be protected.
In this case, the EPA must either
disapprove the Wyoming SIP over the
State’s failure to perform a 110(l)
analysis or prepare its own 110(l)
analysis to demonstrate that the SIP will
not interfere with attainment or
maintenance of the NAAQS.
Furthermore, the EPA must demonstrate
that its FIP will not interfere with
attainment or maintenance of the
NAAQS. The EPA has not done so,
rendering its proposed rule
substantively flawed.
Response: CAA section 110(l)
provides that EPA ‘‘shall not approve a
revision of a plan if the revision would
interfere with any applicable
requirement concerning attainment and
reasonable further progress . . ., or any
other applicable requirement of’’ the
CAA. The commenter has not provided
any evidence that the Wyoming
Regional Haze SIP will interfere with
any applicable requirement concerning
attainment and reasonable progress or
any other applicable requirement of the
CAA, or that further analysis under
110(l) is necessary. To the contrary, the
commenter acknowledges that the
Regional Haze SIP revision will lead to
emission reductions.
The commenter asserts that it is not
enough that the SIP will lead to
emission reductions and that EPA must
determine that the SIP will ensure the
NAAQS are met. We disagree. The CAA
and EPA’s regulations require regional
haze SIPs to address visibility
impairment in mandatory Class I areas;
attainment of the NAAQS is provided
for through a separate SIP process. It is
EPA’s consistent interpretation of
section 110(l) that a SIP does not
interfere with attainment and
maintenance of the NAAQS if the SIP at
least preserves the status quo air quality
by not relaxing or removing any existing
emissions limitation or other SIP
requirements. EPA does not interpret
section 110(l) to require a full
attainment or maintenance
demonstration for each NAAQS for
every SIP revision. See, e.g., Kentucky
Resources Council, Inc., v. EPA, 467
F.3d 986 (6th Cir. 2006); see also, 61 FR
16050, 16051 (April 11, 1996) (actions
on which the Kentucky Resources
Council case were based).
Thus, in this action, we need not
determine whether a 30-day limit is
adequate to protect a shorter-term
NAAQS because the regional haze SIP is
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not required to ensure attainment of the
NAAQS. The fact that the regional haze
SIP specifies 30-day limits will not
preclude Wyoming from adopting limits
with a shorter averaging time, if at some
future date such limits are found to be
necessary and required by the CAA to
protect the NAAQS.
5. Other
Comment: We received over 250
comments in a general mass mailer
campaign in support of our action. We
received over 220 mass mailer
comments on behalf of National Parks
Conservation Association in support of
our action. We also received numerous
general comments from individuals and
organizations in support of our action.
Response: We acknowledge the
commenters’ support of our proposed
action.
Comment: We received over 850 mass
mailer comments opposed to our action.
We also received numerous general
comments from individuals and
organizations in opposition to our
action.
Response: We note the commenters’
opposition to our proposed action.
Comment: We received numerous
general comments in opposition to our
action that stated that the State’s plan
was good enough, that it would achieve
appropriate emission reductions, and
that it represented a balanced approach.
Response: We note the commenters’
opposition to our proposed action.
Comment: We received numerous
general comments in opposition to our
FIP that stated that the visibility in
Wyoming is not hazy and that Wyoming
has some of the best air quality in the
country.
Response: We note the commenters’
general qualitative observations, but
note that the commenters did not
provide any quantitative information to
substantiate their comment.
Comment: We received numerous
comments that we should approve
Wyoming’s SIP because it represents
collaboration between the State,
industry, local governments, and the
public.
Response: We note the commenters’
points, but as stated earlier, EPA can
only approve a state’s SIP if it meets the
requirements of the CAA and EPA’s
implementing regulations.
Comment: We received numerous
comments that EPA’s FIP will only
reduce NOX by 2,900 tpy more than the
Wyoming’s SIP, which reduces NOX by
63,000 tpy. Other commenters went on
to say that EPA’s FIP will basically
achieve the same emission reductions
the State’s SIP would by 2022.
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Response: We disagree with this
comment. EPA’s calculations show that
our proposed FIP will result in
approximately 17,000 tpy more NOX
reductions than the State’s SIP, through
2022 and beyond.
Comment: We received numerous
comments that the proposed FIP, along
with other EPA regulations, are in
support of EPA’s hidden agenda to kill
the coal industry and shut down coalfired power plants.
Response: As stated earlier, EPA’s
proposed action was based on its careful
consideration of the five statutory
factors in the CAA and related statutory
and regulatory requirements.
Comment: We received numerous
comments that the State’s SIP was
created through coordination with
PacifiCorp and other Wyoming
industries and that it is based on sound
science that complies with the CAA and
provides a balance between achieving
compliance with the RHR while
ensuring reliable, affordable electricity.
Response: We note the commenters’
points, but as stated earlier, EPA can
only approve a state’s SIP if it meets the
requirements of the CAA and EPA’s
implementing regulations.
Comment: We received a comment
that it is generally more hazy now than
it was ten years ago and that the
commenter was supportive of reducing
haze.
Response: We note the commenter’s
support.
Comment: We received a comment
that provided data that showed voters in
Wyoming were supportive of continued
implementation of the CAA and
environmental protections for our
environment. The commenter went on
to say that the majority of voters thought
environmental protection and a good
economy were compatible and
encouraged EPA to finalize its proposed
action. The commenter urged EPA to
ignore negative media attention its
action has drawn, stating that the
negative publicity was being driven by
economic interests.
Response: We note the commenter’s
support of our proposed rule.
Comment: EPA has applied selective
comment response to the development
of its re-proposal and the public
comment process, which is
inappropriate. EPA’s process has lacked
transparency, particularly to the State.
EPA has not acknowledged the
Governor’s comments submitted last
year. The EPA has not acknowledged
the DEQ’s comments submitted last
year. DEQ was not consulted in the reproposal process. It would appear that
EPA only considered select comments
that support its predetermined agenda.
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Response: Consistent with our
statutory obligations, we have evaluated
all written and oral comments on the
proposal rulemaking (placing all the
comments received in the docket for
this action at www.regulations.gov);
determined whether any revisions to the
proposed rule are warranted; and
prepared the final rulemaking and
supporting information. The final
rulemaking decisions are accompanied
by the bases for the decisions,
explanations of major changes from the
proposals, and a response to each of the
significant comments submitted in
written or oral presentations during the
comment period, which includes
responses to such comments submitted
by the Governor and DEQ.
Comment: For years, Wyoming has
pursued developing a collaborative and
professional relationship with the EPA,
but with the regional haze SIP process,
the EPA has not reciprocated the same
cooperative effort. This lack of effort on
the part of the EPA does not represent
the intent of what performance
partnership agreements are put in place
to accomplish.
Wyoming is a leader in collaboration.
Whether it is hydraulic fracturing, Sage
Grouse Core Area Development, or
carbon sequestration, Wyoming has
demonstrated a willingness, and really
eagerness, to work with federal
agencies, local government, and
industry to create solutions that not
only minimize detrimental impact, but
may actually do the opposite:
Encouraging sustainable economic
growth in Wyoming.
EPA’s imposition of the FIP would
pour a bucket of cold water on the
solutions resulting from this type of
collaboration. In its place, EPA risks
disenfranchising ratepayers when
industry has little choice but to transfer
the costs associated with retrofitting the
EGUs. Moreover, because EPA failed to
consider the primary cause of regional
haze in Wyoming and the Interior
West—smoke from wildfires—it risks
alienating local government and state
cooperating agencies who will perceive
EPA as being out of touch with the
regulated community.
Response: We disagree with this
comment. EPA values its relationship
with the State of Wyoming and prior to
our proposed action had numerous
meetings with State and industry
representatives to explore ways in
which the State could have addressed
our long standing concerns with the
approvability of the State’s Regional
Haze SIP. Regrettably, we were unable
to find a path forward during those
discussions that could have resulted in
the submission of a fully approvable
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regional haze SIP. Nevertheless, we
remain committed to working
collaboratively with the State on future
regional haze actions and encourage the
State to submit a SIP revision that could
potentially replace all or a portion of
our FIP. We do note that in a previous
action we finalized full approval of the
State’s 309 (SO2) portion of the Regional
Haze SIP. In this action we will also be
finalizing approval of many aspects of
the State’s 309g (NOX and PM) portion
of the regional haze plan.
Comment: We received numerous
comments that the regulation of regional
haze is focused on improving visibility,
not public health.
Response: We agree with the
commenter that the CAA’s visibility
program and the RHR are focused on
improving visibility and not public
health.
Comment: The Conservation
Organizations submitted comments on
July 23, 2012 urging EPA not to finalize
its proposal to approve Wyoming’s
participation in a Western Backstop
Trading Program in lieu of satisfying
BART requirements for SO2. Under 40
CFR 51.309, states within the Grand
Canyon Visibility Transport region,
including Wyoming, may adopt a
BART-alternative for the state’s SO2
emissions provided that, among other
things, the program is shown to provide
for greater reasonable progress than
would be achieved by application of
BART pursuant to 40 CFR 51.308(e)(2).
Wyoming‘s alternative program does not
satisfy this requirement. Accordingly,
Wyoming must comply with BART
requirements for all haze-causing
pollutants, including SO2.
Response: We finalized approval of
the State’s 309 SIP that includes the
requirements for the Western Backstop
Trading Program on December 12, 2012
(77 FR 73926). Because this comment
pertains to that final rulemaking, it is
not germane to this final rulemaking
action.
Comment: Unlike other programs, the
regional haze program requires regular
updates and reviews to ensure that
reasonable progress is being made
towards the ultimate goal ending in
2064. In fact, the State will be required
to submit a progress report to EPA in
2013 and a new regional haze SIP in
2018. EPA should approve the Wyoming
Regional Haze SIP, and reserve most of
its arguments and concerns expressed in
its regional haze FIP for consideration in
Wyoming’s 2018 regional haze SIP
submittals. In the meantime, EPA can be
assured that the significant emission
reductions required under the Wyoming
Regional Haze SIP, nearly all of which
already have been installed, will
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continue to contribute to visibility
improvement.
Response: Because we have found
that the State’s Regional Haze SIP did
not adequately satisfy the RHR
requirements in full, we have a duty to
promulgate a FIP during this planning
period that meets those requirements.
Comment: EPA pays undue attention
to the ‘‘health’’ issues in its FIP. For
reasons it does not explain, EPA’s FIP
discusses the asserted health impacts of
fine particulates, when health impacts
are not part of the BART analysis. The
regional haze program is not a healthbased program; rather, it is focused on
aesthetics.
Response: We disagree with this
comment. In our proposed notice, we
stated that ‘‘PM2.5 can also cause serious
health effects and mortality in humans
and contributes to environmental effects
such as acid deposition and
eutrophication.’’ 78 FR 34741. The
commenter suggests that this brief
informational statement somehow
means that we based our BART
determinations in part on the health
impacts of PM2.5. This is not the case, as
we clearly based our BART
determinations on the five statutory
factors, as required by section 169(a) of
the CAA and the RHR.
Comment: In light of EPA’s apparent
coordination with the special interest
groups and the particular influence
those groups seemed to be exerting over
EPA’s regional haze program, Wyoming
and eleven other states submitted to
EPA a Freedom of Information Act
(FOIA) request seeking communications
between EPA and the special interest
groups related to EPA action on regional
haze SIPs. See Letter from P. Clayton
Eubanks, Deputy Solicitor General,
Office of Oklahoma Attorney General, to
FOIA Officer, EPA (Feb. 6, 2013) (FOIA
Request). EPA denied the states’ public
records request on the ground that the
states’ fee waiver request was invalid
because the states ‘‘have not expressed
a specific intent to disseminate the
information to the public.’’ Letter from
Larry F. Gottesman, National FOIA
Office, EPA, to Clayton Eubanks, Deputy
Solicitor General, Office of Oklahoma
Attorney General (Feb. 22, 2013). But
see FOIA Request, at 5–9 (Feb. 6, 2013)
(describing in detail the states’ intent to
disseminate the information to the
public).
The states appealed that plainly
erroneous decision. See Letter from P.
Clayton Eubanks, Deputy Solicitor
General, Office of Oklahoma Attorney
General, to National FOIA Officer, EPA
(March 15, 2013) (Exhibit 4). On May 2,
2013, EPA’s Office of General Counsel
informed the states that it needed ‘‘a
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brief extension of time’’—until May 15,
2013—to respond to the states’ appeal.
Electronic mail from Lynn Kelly,
Attorney-Advisor, EPA Office of General
Counsel, to P. Clayton Eubanks, Deputy
Solicitor General, Office of Oklahoma
Attorney General. Two weeks later, EPA
again informed the states that it needed
more time to review the appeal,
promising a decision by May 31, 2013.
Electronic mail from Lynn Kelly,
Attorney-Advisor, EPA Office of General
Counsel, to P. Clayton Eubanks, Deputy
Solicitor General, Office of Oklahoma
Attorney General (May 15, 2013).
On that date, EPA denied the states’
FOIA request, claiming the states’
request ‘‘fails to adequately describe the
records sought[.]’’ Letter from Kevin M.
Miller, Assistant General Counsel, EPA
Office of General Counsel, to P. Clayton
Eubanks, Deputy Solicitor General,
Office of Oklahoma Attorney General, at
1 (May 31, 20 13). But see FOIA
Request, at 1–3 (describing in detail the
records sought). In the face of EPA’s
blatant attempts to frustrate the states’
right to access public records directly
related to matters of great importance to
the states and the public, the states sued
EPA in federal court. Compl., Oklahoma
v. EPA, No. 5:13-cv-00726–M (W.D.
Okla. July 16, 2013).
In related litigation seeking the
documents that the states requested, as
well as others, a federal judge has
questioned EPA’s truthfulness and
concluded ‘‘that leaders in EPA may
have purposefully attempted to skirt
disclosure under the FOIA.’’ Mem. Op.,
at 13, Landmark Legal Found. v. EPA,
No. 12–1726 (D.D.C. Aug. 14, 2013).
One cannot help but to similarly
question EPA’s honesty and wonder
what EPA is trying to hide.
Response: EPA disagrees with this
comment. EPA has not coordinated with
environmental organizations regarding
the outcome of this action. As we
explain elsewhere, nothing in the
consent decree requires any particular
substantive outcome concerning
Wyoming’s Regional Haze SIP. With
respect to the allegations made relating
to FOIA litigation, EPA has fully
responded to those claims in federal
court. In any case, the issues in the
FOIA litigation mentioned by the
commenter, such as whether the FOIA
requester reasonably described the
records sought, are unrelated to the
commenter’s unsupported allegations of
coordination with environmental
organizations.
With respect to the commenter’s
insinuations of bias, EPA firmly rejects
them. We have given careful
consideration to all comments and
views submitted, regardless of their
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origin. In response to some comments—
both from industry and from
environmental organizations—we have
acknowledged the merits of the
comments and accordingly adjusted not
only our technical analyses, but also our
final determinations. We have also, at
our discretion, considered comments
from both industry and from
environmental organizations that were
submitted after the close of the
comment period. It is hard to imagine
what better evidence there could be that
EPA is willing and able to rationally
consider arguments and does not have
an unalterably closed mind on the
issues in this action. See Air Transp.
Ass’n of Am., Inc. v. Nat’l Mediation
Bd., 663 F.3d 476, 487 (D.C. Cir. 2010)
(standard for prejudgment of rulemaking
issues) (citing Ass’n of Nat’l Advertisers,
Inc. v. FTC, 627 F.2d 1151 (D.C. Cir.
1979), cert. denied, 447 U.S. 921
(1980)).
VI. Non-Relevant Comments From
EPA’s Original Proposal
The following is a summary of the
significant comments, criticisms, and
new data we received on our initial June
4, 2012 proposed rulemaking, which we
are not responding to because they are
no longer relevant to the action we
proposed on June 10, 2013, or the
specific regional haze related action we
are taking in this final rulemaking.
A. General Comments
Comment: EPA is proposing to
calculate compliance with tons per year
(tpy) BART emissions limits on a rolling
12-month basis. Based on EPA’s
proposal, the owner/operator is to
calculate and record a new 12-month
rolling average emission rate from the
arithmetic average of all valid hourly
emission rates from the continuous
emissions monitoring systems for the
current month and the previous 11
months, and to report the result in tons.
The calculation and compliance
determination shall be performed at the
end of each calendar month.
Wyoming established BART
emissions limits based on a 30-day
rolling average in accordance with 40
CFR part 51 Appendix Y. Wyoming also
established annual emissions limits for
units with BART limits. For all units
with BART limits, except Units 1
through 3 at Basin Electric’s Laramie
River Station, Wyoming based the
annual emissions limits on the 30-day
averaged lb/hr emissions limit and fulltime operation for 8,760 hours per year.
Wyoming deliberately established
these limits on a calendar year basis to
reduce recordkeeping and reporting
burdens, without being any less
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stringent than what was prescribed
under Appendix Y. Every year, when
the Title V emissions inventory is
submitted for each of these facilities, the
reported annual emissions can be
compared to the annual BART limits
established in the State permits to
determine compliance. Requiring
compliance with a 12-month rolling
average will result in unnecessary
monitoring, recordkeeping, and
reporting, as the 12-month rolling
emissions limit would be based on fulltime operation of the unit and the more
stringent 30-day averaged lb/hr value.
Comment: We received a comment
from a coalition of physicians that
expressed concerns over the health
impacts from air pollution, particularly
particulate matter and ozone.
Comment: We received a comment
from a member of the public that points
out the amount of coal production in
Wyoming and its contribution to carbon
dioxide and climate change.
B. Basin Electric Laramie River
Comment: Wyoming has
overestimated the ability of SNCR to
reduce emissions. EPA is basing its
BART determination on the assumption
that LNB+OFA+SNCR can achieve 0.12
lb/MMBtu on a 30-day rolling average.
This means that addition of SNCR must
reduce NOX emissions from the
LNB+OFA strategy by another 48%.
Given the sensitivity of SNCR to boiler
operation, size, and configuration, we
are concerned that SNCR may not be
able to achieve the proposed level of
performance on a consistent basis. For
example, our query of CAMD data for
2011 found no EGUs with SNCR (out of
3,621 coal-fired EGUs) that met 0.12 lb/
MMBtu each month.
Comment: EPA should ensure that
SNCR plus LNBs/OFA are capable of
meeting the proposed NOX limit of 0.12
lb/MMBtu, which would reflect a 43%
NOX removal efficiency for SNCR. This
level of removal is approximately twice
that considered for other Wyoming
facilities, as well as facilities in other
state BART analyses. Further, in
commenting on EPA’s BART proposal
for Montana’s Colstrip Units 1 and 2,
the NPS researched 3,621 coal-fired
EGUs with SNCR and found only two
units that could meet 0.15 lb/MMBtu
consistently on a monthly basis.
Accordingly, we question whether
SNCR plus combustion controls can
achieve a 0.12 lb/MMBtu NOX limit at
Laramie River Station Units 1–3. Should
EPA find that this level of control with
SNCR is achievable, and fail to impose
adequate BART limits reflective of SCR
capabilities; we request the EPA ensure
the proposed NOX limits are made
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enforceable as a backstop and that if
greater removal efficiencies are
achievable, rates be revised downwards
within a 12-month period from the date
the technology becomes operable. We
also request that level of ammonia slip
not exceed 5ppm, and such limit
likewise be made enforceable.
Comment: EPA’s BART analysis for
Laramie River Station Units 1–3
improperly relied on cost estimates from
Basin Electric that overestimated capital
costs and significantly underestimated
operation and maintenance costs for
SNCR. Particularly, Basin Electric
underestimated the cost of reagent. We
corrected these errors in our revised cost
calculation using the Sargent & Lundy
SNCR cost module from the IPM, and
evaluated the cost of SNCR to reduce
NOX from the 0.21 lb/MMBtu Wyoming
BART limit for LNBs/OFA down to
EPA’s proposed FIP limit of 0.12 lb/
MMBtu which reflects a NOX reduction
across the SNCR of 43%. We also
evaluated the cost effectiveness for an
SNCR system designed to achieve 20%
NOX removal, which would equate to a
NOX rate of 0.17 lb/MMBtu. Our revised
estimates show the cost effectiveness of
SNCR plus combustion controls is
between $2,435/ton and $2,623/ton to
meet a 0.12 lb/MMBtu NOX rate (or
between $2,062/ton and $2,368/ton to
meet a 0.17 lb/MMBtu NOX rate). These
corrected cost effectiveness values for
meeting a 0.12 lb/MMBtu NOX rate with
SNCR are higher than the cost
effectiveness values, between $2,056/
ton and $2,109/ton, assumed by EPA.
Comment: EPA relied on SCR cost
estimates provided by Basin Electric
that failed to include LNBs/OFA and
therefore assumed unreasonably high
construction and operation costs for the
SCR.
Comment: A comparison of SCR to
EPA’s preferred LNB+OFA+SNCR
option shows incremental costs less
than $4,000/ton which are well below
values EPA typically accepts. For
example, in its proposal to disapprove
part of the North Dakota plan, EPA cited
the ‘‘. . . relatively low incremental
cost effectiveness between the two
control options ($4,855 per ton) . . .’’
For Laramie River Station, the National
Park Service (NPS) estimates of
incremental costs of SCR are only
slightly greater than SCR’s average costs,
which are reasonable when compared to
costs accepted by other states and EPA.
Comment: Although Basin Electric
opposes EPA’s SIP disapproval and FIP,
it supports the agency’s decision not to
require SCR at Laramie River Station in
its proposed FIP. EPA eliminated the
option of LNBs/OFA plus SCR from
consideration as BART for the Laramie
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River Station because ‘‘the cost
effectiveness value is significantly
higher than LNBs with OFA and there
is a comparatively small incremental
visibility improvement over LNBs with
OFA.’’ Basin Electric agrees with and
supports the EPA on this issue.
Comment: EPA’s analysis for Basin
Electric’s Laramie River Station
acknowledged that additional emissions
reductions from LNB and OFA were
proposed in the SIP, but did not assess
the benefit of these lower emissions
rates. The short term mass emissions
rate was reduced to 1,220 lb/hr for
Laramie River Station on Units 1 and 2,
and reduced to 1,254 lb/hr for Laramie
River Station Unit 3. EPA explained that
since the State did not provide
additional cost information for the
lower limits, revised modeling based on
0.21 lb/MMBtu was not performed, nor
did EPA perform a revised cost analysis.
The reduced mass emissions are
based on a performance level of 0.19 lb/
MMBtu, which will be achieved by the
installation of LNB with OFA at no
additional cost. Accounting for
additional reduction in emissions,
without changing the control costs,
yields a significantly higher incremental
cost, approximately $3,300, between
LNB with OFA and SNCR. If EPA had
accounted for additional reduction from
LNB and OFA and resulting smaller
incremental visibility improvement (less
than 0.23 delta deciviews), the State
anticipates that SNCR would not have
been BART. This conclusion is based on
EPA’s determination in the proposed
FIP for Montana that ‘‘. . . the cost of
SOFA+SCR ($3,195/ton) [lower than the
incremental cost of SNCR] is not
justified by the visibility improvement
of 0.404 deciviews at Theodore
Roosevelt National Park and 0.378
deciviews at UL Bend.’’ 77 FR 24027.
When evaluating Wyoming’s 309(g)
Regional Haze SIP, EPA should have
considered the additional NOX
emissions reductions achieved in the
SIP before making a final determination
on the approvability of the SIP.
Comment: EPA’s comparison of
annual emissions from the installation
of SNCR to the annual emissions cap
established in a settlement is not
consistent. Operation of SNCR on
Laramie River Station Units 1 through 3
is anticipated to result in annual
emissions of 8,468 tons per year. The
State established an annual facility
emissions cap of 12,773 tons per year in
a permit. The 8,468 tons per year value
is based on an average of 2001–2003
actual heat input for each boiler, while
the 12,773 tons of NOX is a facility cap
on potential emissions. Typically, actual
emissions are notably less than potential
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emissions in order to maintain a margin
of compliance. It is the State’s
expectation that the emissions
difference between EPA’s SNCR
determination and the State’s reduced
facility emissions cap will be less than
the calculated 4,305 tons per year. A
more direct comparison would be to
base the difference on the potential to
emit for each of the three Laramie River
Station units (0.12 lb/MMBtu times the
maximum heat input rate times 8,760
hours of operation) which yields an
annual facility NOX emission rate of
10,218 tons per year, and a difference
from the State’s emission cap of 2,555
tons.
Comment: EPA states ‘‘We find it was
unreasonable for the State not to
determine that LNBs with OFA plus
SNCR was NOX BART for LRS Units 1–
3.’’ This statement provides no insight
into the agency’s reasons for
disapproving the State’s NOX BART for
Laramie River Station.
C. Jim Bridger Units 1–4
Comment: In its regional haze FIP,
EPA identifies the relatively high
incremental cost effectiveness of SCR
($5,721 per ton) for the Bridger units.
Nevertheless, EPA does not account for
this number in its own BART decision
making. EPA also fails to accord any
deference to Wyoming’s consideration
of these same costs. Such action is
arbitrary and contrary to EPA’s actions
in other states. Here, EPA erred by not
considering any incremental costs for
Bridger, and by not honoring
Wyoming’s consideration of costs for
the Bridger units.
Comment: In response to EPA’s
request for comment on alternative
approaches for the Jim Bridger BART
determination, EPA received general
comments in favor of our third proposal
in the alternative. Although these
commenters supported our third
proposal in the alternative, the
commenters did not provide
quantitative information to support their
position.
Comment: EPA is seeking comment
on an alternative that would allow
PacifiCorp to install SCR at Jim Bridger
Units 3 and 4 within 5 years from the
date of EPA’s final action. EPA’s
reasoning is that this alternative would
allow PacifiCorp the flexibility to
determine the implementation schedule
for BART controls on all four Jim
Bridger units. Because EPA’s initial
proposal to require BART installation by
2016 best complies with the statutory
requirement that BART be installed and
operated as expeditiously as practicable,
42 U.S.C. 7491(b)(2)(A), we support
EPA’s proposal over the alternative.
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Comment: EPA likely underestimated
the visibility benefits attributable to SCR
to control NOX emissions in other ways.
First, EPA failed to follow its BART
guidelines in estimating pre- and postcontrol emissions. EPA’s baseline for
modeling included the PM and SO2
limits that will be established by the
regional haze plan, rather than using a
pre-SIP baseline (typically from the time
period of 2001–2004) as required by
EPA’s BART guidelines. This approach
resulted in an understatement of
visibility improvement from NOX BART
controls. Further, EPA deviated from its
BART guidelines by modeling baseline
emissions that were based on allowable
emission rates rather than actual
maximum 24-hour rates. As a result,
EPA’s baseline is based on long-term
average emissions that mask actual
maximum visibility impairment.
Further, EPA greatly overestimates the
ammonia slip (SO4 emissions)
associated with SCR. For example,
actual increases in SO4 emissions due to
operation of SCR at each of the Jim
Bridger units are 7.89 lb/hr per unit, far
lower than EPA’s assumed increase in
SO4 emissions of 54.0 lb/hr per unit.
This error, too, likely caused EPA to
understate the visibility benefits of SCR.
The Conservation Organizations
conducted modeling analyses to
examine how widespread the impacts
from each BART-subject source were
and to analyze the widespread visibility
improvements that would result if all
units were required to install SCR along
with combustion controls at 0.05 lb/
MMBtu limits routinely achieved to
meet NOX BART. The Conservation
Organizations did not attempt to
address all of EPA‘s errors in their
supplemental modeling of visibility
impacts. Had the Conservation
Organizations done so (i.e., changed
baseline to reflect pre-SIP emissions of
SO2, PM as well as NOX, and reduced
the projected increase in sulfates to
more reasonable levels), we assume that
even greater visibility benefits would
have been demonstrated with SCR
required as BART at all BART-subject
units.
D. Dave Johnston Units 3 and 4
Comment: EPA relied on Wyoming’s
cost-effectiveness analysis of SCR plus
LNBs/OFA at Dave Johnston Unit 3,
which significantly overestimates the
cost of this technology. While EPA
presented a cost effectiveness of $3,243/
ton, our revised cost-effectiveness
calculation using the Sargent & Lundy
SCR cost module shows that SCR plus
LNBs/OFA at Dave Johnston Unit 3 to
meet a NOX limit of 0.05 lb/MMBtu is
much lower: $1,632/ton.
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Comment: EPA relied on Wyoming’s
dramatic underestimation of the cost for
SNCR at Dave Johnson Unit 3.
Wyoming’s BART analysis used costs
provided by PacifiCorp, which greatly
underestimated reagent costs for SNCR.
Further, although PacifiCorp’s SNCR
cost analysis was based on achieving a
NOX rate of 0.22 lb/MMBtu, Wyoming
stated that SNCR was assumed to meet
a NOX rate of 0.19 lb/MMBtu. This
skewed the cost-effectiveness results by
making SNCR appear less costly and
more effective. Our revised analysis
using the Sargent & Lundy SNCR cost
module from the IPM to achieve a 0.22
lb/MMBtu NOX rate (20% removal
across the SNCR) demonstrated that
SNCR has a higher cost-effectiveness
value than is presented in the proposed
rule. While EPA presented and relied on
a cost effectiveness for SNCR of $721/
ton, correcting the flaws in that analysis
demonstrates a cost effectiveness for
SNCR of $1,443/ton. Based on these
corrected cost calculations, the cost of
SCR plus LNBs/OFA is $1,632/ton, not
appreciably higher than the cost of
SNCR at $1,443/ton.
Comment: EPA makes the same errors
in its BART analysis for Dave Johnston
Unit 4 as it did for Unit 3. EPA has
proposed to approve Wyoming’s NOX
BART determination for Dave Johnston
Unit 4, requiring LNBs with advanced
OFA to achieve a NOX emission limit of
0.15 lb/MMBtu. Although the cost
effectiveness of SCR plus LNBs with
OFA at Dave Johnston Unit 4 presented
by Wyoming and relied upon by EPA
was abundantly reasonable at $2,210 per
ton of NOX removed, EPA apparently
agreed with Wyoming that the
incremental cost effectiveness of these
controls compared to LNBs/OFA was
too high to justify SCR as BART.
Wyoming calculated the cost
effectiveness of SCR plus LNBs/OFA to
be $2,210/ton with a projected
maximum visibility improvement of
0.97 deciviews. In comparison,
Wyoming and EPA found that these
same controls constitute BART at
Naughton Unit 3, even though the cost
was greater, $2,830/ton, and the
projected maximum visibility
improvement was roughly the same, 1.0
deciviews. Wyoming and EPA also
found that SCR plus LNBs and SOFA
met BART for Jim Bridger Units 3 and
4 at a cost effectiveness of $2,258/ton
and a projected visibility improvement
of 0.80 and 0.82 deciviews, respectively.
Further, EPA found that SCR plus LNBs
and SOFA met BART for Jim Bridger
Units 1 and 2 at a cost effectiveness of
$2,258/ton and a visibility improvement
of 0.76 deciviews and 0.82 deciviews,
respectively. EPA’s contrary conclusion
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for Dave Johnston Unit 4 is arbitrary and
inconsistent with EPA’s other decisions.
Comment: Although EPA’s data in the
proposed rule demonstrated that SCR
plus LNBs/OFA is cost effective at
$2,210/ton of NOX removed, EPA
overestimated the cost of SCR for Dave
Johnston Unit 4 in the same way it did
for Dave Johnston Unit 3. We
recalculated the cost effectiveness of
SCR plus combustion controls at Dave
Johnston Unit 4 using the Sargent &
Lundy SCR IPM Cost Module to meet a
NOX rate of 0.05 lb/MMBtu. The revised
cost analysis shows a cost effectiveness
of $1,837/ton for these controls.
Comment: EPA appears to have
placed undue weight on incremental
costs. In its proposal to disapprove part
of the North Dakota plan, EPA cited the
‘‘. . . relatively low incremental cost
effectiveness between the two control
options ($4,855 per ton) . . .’’ For
Johnston units 3 and 4, the NPS
estimates of incremental costs of SCR
are two—three times greater than
LNB+OFA+SCR’s average costs, which
are reasonable when compared to costs
accepted by other states and EPA.
E. Naughton Units 1–3
Comment: We received comments
that the cost analysis of SCR at
Naughton is over inflated. One
commenter estimated that, using a
capital cost of $266/kW,
LNB+OFA+SCR for Unit 1 would
remove 3,249 tpy and cost $2,098/ton.
The commenter went on to say that they
estimated the cost for the addition of
SCR to Unit 2 and Unit 3 would be
$2,037 and $2,844/ton. A commenter
estimated the costs for the addition of
SCR to Unit 3 would be $1,788/ton.
Another commenter estimated the cost
of SCR of $1,550/ton for Naughton Unit
1 and $1,501/ton for Naughton Unit 2.
Comment: Even taken at face value,
the $2,750 and $2,848 costs per ton
estimated by Wyoming for LNB+OFA+
SCR on Naughton Units 1 and 2,
respectively, are similar to or lower than
the cost/ton values accepted as
reasonable in other BART analyses,
including Wyoming’s and EPA’s
conclusion that addition of OFA+SCR at
$2,830/ton is reasonable for Naughton
Unit 3.
Comment: Despite our concerns with
the visibility modeling conducted by
EPA, taken at face value, the annual
costs and visibility improvements
(presented by EPA) associated with the
addition of SCR result in costeffectiveness of $9.6 million/deciview
for Naughton Unit 1, $11.5 million/
deciview for Unit 2, and $15.7 million/
deciview for Unit 3 (which EPA deemed
reasonable) at the nearest Class I area.
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All three of these estimates are below or
within the range of average cost/
deciview accepted as ‘‘reasonable’’.
Comment: EPA relied solely on an
incremental cost-benefit rationale to
reject SCR as BART for Naughton Units
1 and 2. This conclusion is improper
where SCR plus combustion controls is
cost effective, even using EPA’s inflated
numbers, and its visibility benefit
would be significant. Indeed, the costs
and visibility benefits of SCR at Units 1
and 2 are nearly identical to the costs
and visibility benefits of SCR at Unit 3,
at which EPA found SCR to be BART.
Specifically, SCR at Naughton Units 1
and 2 has a cost effectiveness of $2,750/
$2,848 per ton of NOX removed and
results in maximum visibility
improvements of 1.07/1.10 deciviews.
Given these very similar numbers,
EPA’s determination that SCR is BART
at Unit 3 but SCR is not BART at Units
1 and 2 is arbitrary.
Comment: EPA has placed undue
emphasis on incremental cost
effectiveness is even more improper
considering its inaccuracy. EPA stated
incorrectly the incremental cost
effectiveness of LNBs/OFA plus SCR
compared to LNBs/OFA as $8,000/ton.
However, this calculation actually refers
to the incremental cost effectiveness of
the SCR option compared to the SNCR
BART option. The incremental cost
effectiveness between the SCR option
and the LNB/OFA option based on
Wyoming’s cost and emission estimates
provided in its BART Application
Analyses are $6,665/ton for Unit 1 and
$6,518/ton for Unit 2.
F. Wyodak
Comment: We received comments
that the costs for SCR were overinflated.
One commenter estimated that
LNB+OFA+SCR would remove 3,773
tpy and cost $3,475/ton. Another
commenter estimated that based on the
Sargent & Lundy SCR cost module, the
revised cost estimate for these controls
to meet a NOX limit of 0.05 lb/MMBtu
is $2,602/ton of NOX removed.
Comment: As it did for Dave Johnston
Unit 3, EPA also relied on Wyoming’s
gross underestimate of the costs of
SNCR. Rather than the $958/ton of NOX
removed assumed by EPA, the more
accurate cost effectiveness of SNCR
based on the Sargent & Lundy SNCR
IPM cost module is $3,139/ton. Thus,
SCR is more cost effective than SNCR to
control NOX at Wyodak.
Comment: EPA has placed undue
weight on incremental costs and
incremental benefits. Our analysis of the
LNB+OFA+SCR option shows an
incremental cost of $3,726/ton for
adding SCR to LNB+OFA. Our estimates
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of incremental costs of SCR are only
slightly greater than LNB+OFA+SCR’s
average costs, which are reasonable
when compared to costs accepted by
other states and EPA.
G. Dave Johnston Units 1 and 2
Comment: The Conservation
Organizations agree with EPA that
reasonable progress controls for NOX
emissions are needed for Dave Johnston
Units 1 and 2. EPA correctly found that
it was unreasonable for Wyoming to
reject cost effective NOX controls that
would improve visibility. EPA proposes
to require only LNBs/OFA to achieve a
NOX emission limit of 0.20 lb/MMBtu
(30-day rolling average). While we
commend EPA for proposing a FIP to
reduce NOX emissions from Dave
Johnston Units 1 and 2, we urge EPA to
require SCR plus LNBs/OFA to meet a
NOX emission limit of 0.05 lb/MMBtu to
achieve reasonable progress. Although
EPA concluded that the cost of SCR is
not justified by the projected visibility
improvement, EPA’s analysis
unreasonably assumed that SCR would
only achieve a NOX emission rate of
0.12 lb/MMBtu, even though an
emission rate of 0.05 lb/MMBtu is
readily achievable. Correcting for this
error, it appears that SCR at Dave
Johnston Units 1 and 2 is very cost
effective at $2,001 and $1,987/ton of
NOX removed, respectively.
Accordingly, EPA should reconsider
requiring SCR at Dave Johnston Units 1
and 2 to meet reasonable progress
requirements.
Comment: EPA deviated from the
BART Guidelines in the way it
estimated the emission rates it used in
its modeling analyses. For Dave
Johnston Unit 1 and Unit 2, EPA
assumed that NOX emissions would
drop from 1,012.5 lb/hr (base case) to
354.375 lb/hr with the addition of
LNB+OFA and to 202.5 lb/hr with
addition of SCR. However, our review of
2001–2003 daily CAMD data found that
daily NOX emissions from Johnston Unit
1 and Unit 2 during 2001–2003 never
exceeded 680 lb/hr. EPA modeling
analysis cannot be relied upon to
estimate ‘‘a comparatively small
incremental visibility improvement’’
because the emissions modeled are
incorrect.
Comment: The EPA conclusion that
the addition of SCR is not justified due
to the ‘‘small incremental visibility
improvement’’ is based upon a flawed
visibility analysis that over-values the
addition of LNB+OFA and under-values
addition of SCR. Furthermore, the
degree of visibility improvement is not
one of the four statutory factors to be
considered under the reasonable
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progress provisions of the RHR.
Incremental visibility improvement is
not mentioned anywhere in the
reasonable progress provisions or BART
Guidelines and EPA cannot create a new
criterion for the sole purpose of
eliminating a control option that is
reasonably cost-effective and would
yield a significant visibility
improvement.
H. Modeling
Comment: EPA conducted visibility
impact modeling from the Wyoming
sources for its BART and reasonable
progress analyses. Unfortunately, EPA
failed to present and/or fully explain the
results of its modeling to the public,
thus preventing a complete analysis of
the benefits of installation of SCR on the
Wyoming sources. Accordingly, we
request that EPA provide clarification
on the following issues: (1) Please
clarify whether the spreadsheet
provided in response to our FOIA
request represents EPA’s complete and
final modeling results. If not, we request
that EPA post all final visibility
modeling results to the docket for this
rulemaking, including any postprocessing of modeling results, and
allow the public to submit comment on
the modeling results; (2) Please describe
and clarify any discrepancies between
EPA’s proposed rule and its final
modeling results; (3) Please explain how
EPA calculated the visibility results
presented in its proposed rule and
provide all data upon which these
calculations were made. In addition, we
request that EPA re-run its visibility
impact modeling for years 2001–2003
and incorporate all proposed changes to
its modeling provided in this comment
letter, in the TSD, and in the Expert
Report of Howard Gebhart, including,
but not limited to utilization of the
correct version of the model, correct
emission rates, and compressive
inclusion of impacted Class I areas. We
also request that EPA post its new
corrected modeling results to the docket
for this rulemaking and provide the
public with an adequate opportunity to
respond and comment on the new
visibility impact modeling.
Comment: Wyoming DEQ evaluated
visibility improvements at the three
nearest Class I areas—Bridger,
Fitzpatrick, and Mount Zirkel
Wilderness Areas—and reported the
‘‘cumulative 3-year averaged visibility
improvement from Post-Control
Scenario A across the three Class I areas
. . .’’ We requested to DEQ that the
other eight Class I areas within 300 km
of Bridger (Grand Teton National Park,
Yellowstone National Park, Rocky
Mountain National Park, Washakie
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Wilderness Area, Teton Wilderness
Area, Flat Tops Wilderness Area, Rawah
Wilderness Area, and Eagles Nest
Wilderness Area) be included in the
modeling analysis. However, instead of
expanding the modeling analysis, EPA
R8 reported results for only the Mount
Zirkel Wilderness Area.
Comment: EPA R8 has incorrectly
estimated visibility improvement from
all NOX control options: WY DEQ
evaluated visibility improvements at the
four nearest Class I areas and reported
the ‘‘The cumulative 3-year averaged
98th percentile visibility improvement
from Post-Control Scenario A summed
across all four Class I areas achieved
with Post-Control Scenario B was 0.754
delta deciviews from Unit 3 and 0.405
delta from Unit 4.’’ EPA R8 reported
results for only one Class I area.
PacifiCorp apparently considered cost a
useful metric when it made the
following statements for its Unit #3
BART proposal: ‘‘the incremental cost
effectiveness for Scenario 1 compared to
the Baseline is reasonable at $0.4
million per day and $14.4 million per
deciview to improve visibility at
Badlands NP’’ and for its Unit #4 BART
proposal, ‘‘the incremental cost
effectiveness for Scenario 1 compared to
the Baseline is reasonable at about
$800,000 per day and $31.7 million per
deciview.’’ PacifiCorp’s conclusions are
consistent with those reached across the
country that the average cost per
deciview proposed by either a state or
a BART source is $14–$18 million, with
a maximum of almost $50 million per
deciview proposed by Colorado at the
Martin Drake power plant. Combining
the modeling results provided by EPA
R8 (which we believe have
underestimated SCR benefits) and
Wyoming DEQ’s cost analyses (which
we believe have overestimated SCR
costs), addition of SCR at Dave Johnston
Unit 3 would improve visibility by 1.16
deciview at a cost of $14 million per
deciview at the most-impacted Class I
area. Likewise, addition of SCR at Dave
Johnston Unit 4 would improve
visibility by 0.97 deciview at a cost of
$17 million per deciview. Not only is
addition of SCR cost-effective (even by
PacifiCorp’s criteria), it would be even
more cost-effective if the issues we have
noted above are addressed. By
overestimating costs of SCR and
underestimating control efficiency and
visibility benefits, EPA R8 concluded
that combustion controls plus SNCR is
BART for Unit 3 and combustion
controls are BART for Unit 4, rather
than SCR.
Comment: EPA states that a change of
1.0 deciview is perceptible and causes
visibility impairment and a change of
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0.5 deciviews, although not perceptible,
is considered to contribute to visibility
impairment. 40 CFR part 51, App. Y,
section III.A.1, 70 FR 39120. Sources
that do not have an impact of 0.5
deciviews or more may be exempted
from BART altogether. 40 CFR part 51,
App. Y, section III.A.1. In Wyoming,
EPA approved the State’s selection of a
0.5 deciview threshold for exempting
sources from BART, based on the
‘‘relatively limited impact on visibility’’
from sources under the threshold.
In Colorado, the state established
criteria that SNCR would be required as
BART only if the cost effectiveness for
SNCR was less than $5,000/ton and the
visibility improvement was greater than
0.2 deciviews. Although EPA stated it
did ‘‘not necessarily agree’’ that these
criteria would always be appropriate for
determining BART, it proposed to
approve all BART determinations the
state made using these criteria.
The modeled visibility improvement
using the final BART permit levels that
would be achieved with SNCR at
Laramie River is one-tenth of what EPA
contends is humanly perceptible, onefifth of the level used to exempt
Wyoming sources from BART due to
relatively limited visibility impact, and
one-half the SNCR threshold used by
Colorado to establish limits that EPA
proposed to approve. This de minimis
improvement rebuts EPA’s disapproval
of the State’s NOX BART for Laramie
River, and supports the State’s final
BART determination. Even if EPA were
entitled to disapprove a state’s BART
determination based on a standard of
‘‘unreasonableness,’’ it cannot be
unreasonable for the state to fail to
require additional SNCR controls that
would offer tiny and imperceptible
visibility improvements at enormous
cost. However one characterizes the
facts, millions of dollars would be spent
every year to install and operate SNCR.
Moreover, the modeled visibility
improvements for the Jim Bridger units
resulting from the requirement to install
SCR (as BART under the EPA regional
haze FIP and as part of the LTS under
the Wyoming Regional Haze SIP) are too
small to justify the overall expense of
requiring these controls. Spending
hundreds of millions of dollars for
imperceptible visibility changes does
not meet the intent, or purpose, of the
regional haze program.
Comment: EPA has improperly failed
to account for the very few number of
days of visibility impacts or the seasonal
timing of when those few impacts occur.
EPA is proposing to accelerate the
timeline for installing the Jim Bridger
Unit 1 SCR from 2022 to 2017 and the
Jim Bridger Unit 2 SCR from 2021 to
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5217
2017. Even when relying on the
CALPUFF models that significantly
overestimate the visibility impacts,
EPA’s proposal will only result in
imperceptible visibility improvements
for only eleven days a year until the
SCRs would have been installed as
required by the State’s plan.
In a similar manner, the days of
impacts need to be considered when
evaluating the additional controls that
EPA proposes to install on Wyodak and
Dave Johnston Unit 3. EPA’s modeling
of Wyodak indicates that installing and
incurring the additional costs for the
SNCR will not only result in an
imperceptible 0.15 deciview of visibility
improvement, but the days per year the
unit is modeled to impact the park by
greater than 0.5 deciviews will be
reduced from sixteen to twelve days; a
benefit of only four days per year.
EPA’s modeling of Dave Johnston
Unit 3 indicates that installing and
incurring the additional costs for SNCR
will result not only in an imperceptible
0.17 deciview improvement, but the
days per year the unit is modeled to
impact the park by greater than 0.5
deciviews will only be reduced from
nine to six days; a benefit of only three
days per year. None of these
imperceptible modeled visibility
improvements occurring during only a
few days a year justify the tremendous
cost of controls required under EPA’s
regional haze FIP.
VII. Statutory and Executive Order
Reviews
A. Executive Order 12866: Regulatory
Planning and Review and Executive
Order 13563: Improving Regulation and
Regulatory Review
This action is not a ‘‘significant
regulatory action’’ under the terms of
Executive Order 12866 (58 FR 51735,
October 4, 1993) and is therefore not
subject to review under Executive
Orders 12866 and 13563 (76 FR 3821,
January 21, 2011). As discussed in
section C below, the final FIP applies to
only three facilities and five BART
units.241 It is therefore not a rule of
general applicability.
B. Paperwork Reduction Act
This action does not impose an
information collection burden under the
provisions of the Paperwork Reduction
Act, 44 U.S.C. 3501 et seq. Burden is
defined at 5 CFR 1320.3(b). Because the
final FIP applies to just three facilities,
the Paperwork Reduction Act does not
apply. See 5 CFR 1320(c).
241 Dave Johnston Unit 3, Laramie River units 1,
2, and 3, and the unit at Wyodak.
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C. Regulatory Flexibility Act
The Regulatory Flexibility Act (RFA)
generally requires an agency to prepare
a regulatory flexibility analysis of any
rule subject to notice and comment
rulemaking requirements under the
Administrative Procedure Act or any
other statute unless the agency certifies
that the rule will not have a significant
economic impact on a substantial
number of small entities. Small entities
include small businesses, small
organizations, and small governmental
jurisdictions.
For purposes of assessing the impacts
of today’s final rule on small entities,
small entity is defined as: (1) A small
business as defined by the Small
Business Administration’s (SBA)
regulations at 13 CFR 121.201; (2) a
small governmental jurisdiction that is a
government of a city, county, town,
school district or special district with a
population of less than 50,000; and (3)
a small organization that is any not-forprofit enterprise which is independently
owned and operated and is not
dominant in its field.
After considering the economic
impacts of today’s final rule on small
entities, I certify that this action will not
have a significant economic impact on
a substantial number of small entities.
The Regional Haze FIP that EPA is
finalizing for purposes of the regional
haze program consists of imposing
federal controls to meet the BART
requirement for NOX emissions on five
specific BART units at three facilities in
Wyoming. The net result of this FIP
action is that EPA is finalizing direct
emission controls on selected units at
only three sources. The sources in
question are each large electric
generating plants that are not owned by
small entities, and therefore are not
small entities. The final partial approval
of the SIP merely approves state law as
meeting Federal requirements and does
not impose additional requirements.
See, e.g., Mid-Tex Electric Cooperative,
Inc. v. FERC, 773 F.2d 327 (D.C. Cir.
1985)(hereinafter Mid-Tex).
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D. Unfunded Mandates Reform Act
(UMRA)
Title II of the Unfunded Mandates
Reform Act of 1995 (UMRA), Public
Law 104–4, establishes requirements for
federal agencies to assess the effects of
their regulatory actions on State, local,
and Tribal governments and the private
sector. Under section 202 of UMRA,
EPA generally must prepare a written
statement, including a cost-benefit
analysis, for final rules with ‘‘Federal
mandates’’ that may result in
expenditures to State, local, and Tribal
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governments, in the aggregate, or to the
private sector, of $100 million or more
(adjusted for inflation) in any one year.
Before promulgating an EPA rule for
which a written statement is needed,
section 205 of UMRA generally requires
EPA to identify and consider a
reasonable number of regulatory
alternatives and adopt the least costly,
most cost-effective, or least burdensome
alternative that achieves the objectives
of the rule. The provisions of section
205 of UMRA do not apply when they
are inconsistent with applicable law.
Moreover, section 205 of UMRA allows
EPA to adopt an alternative other than
the least costly, most cost-effective, or
least burdensome alternative if the
Administrator publishes with the final
rule an explanation why that alternative
was not adopted. Before EPA establishes
any regulatory requirements that may
significantly or uniquely affect small
governments, including Tribal
governments, it must have developed
under section 203 of UMRA a small
government agency plan. The plan must
provide for notifying potentially
affected small governments, enabling
officials of affected small governments
to have meaningful and timely input in
the development of EPA regulatory
actions with significant federal
intergovernmental mandates, and
informing, educating, and advising
small governments on compliance with
the regulatory requirements.
Under Title II of UMRA, EPA has
determined that this final rule does not
contain a federal mandate that may
result in expenditures that exceed the
inflation-adjusted UMRA threshold of
$100 million ($150 in 2013 when
adjusted for inflation) by State, local, or
Tribal governments or the private sector
in any one year. The private sector
expenditures that will result from the
FIP, including BART controls for Basin
Electric Laramie River Station Units 1–
3 ($67,128,584 per year) 242, and
PacifiCorp Dave Johnston Unit 3
($11,680,144 per year) 243 and Wyodak
($15,073,502) 244, are $93,882,230 per
year. This calculation assumes that
PacifiCorp would choose to install SCR
on Dave Johnston Unit 3, and not to
otherwise voluntarily retire the unit, an
option which the FIP allows.
242 Andover Technology Partners, ‘‘Cost of NO
X
Controls on Wyoming EGUs’’, October 28, 2013;
Wyoming EGU BART and Reasonable Progress
Costs—10/2013.
243 Andover Technology Partners, ‘‘Cost of NO
X
Controls on Wyoming EGUs’’, October 28, 2013;
Wyoming EGU BART and Reasonable Progress
Costs—10/2013.
244 Andover Technology Partners, ‘‘Cost of NO
X
Controls on Wyoming EGUs’’, October 28, 2013;
Wyoming EGU BART and Reasonable Progress
Costs—10/2013.
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Additionally, we do not foresee
significant costs (if any) for state and
local governments. Thus, because the
annual expenditures associated with the
FIP are less than the inflation-adjusted
threshold of $150 million in any one
year, this rule is not subject to the
requirements of sections 202 or 205 of
UMRA. This rule is also not subject to
the requirements of section 203 of
UMRA because it contains no regulatory
requirements that might significantly or
uniquely affect small governments.
E. Executive Order 13132: Federalism
Executive Order 13132, Federalism,
(64 FR 43255, August 10, 1999) revokes
and replaces Executive Orders 12612
(Federalism) and 12875 (Enhancing the
Intergovernmental Partnership).
Executive Order 13132 requires EPA to
develop an accountable process to
ensure ‘‘meaningful and timely input by
State and local officials in the
development of regulatory policies that
have federalism implications.’’ ‘‘Policies
that have federalism implications’’ is
defined in the Executive Order to
include regulations that have
‘‘substantial direct effects on the States,
on the relationship between the national
government and the States, or on the
distribution of power and
responsibilities among the various
levels of government.’’ Under Executive
Order 13132, EPA may not issue a
regulation that has federalism
implications, that imposes substantial
direct compliance costs, and that is not
required by statute, unless the federal
government provides the funds
necessary to pay the direct compliance
costs incurred by state and local
governments, or EPA consults with state
and local officials early in the process
of developing the final regulation. EPA
also may not issue a regulation that has
federalism implications and that
preempts state law unless the Agency
consults with state and local officials
early in the process of developing the
final regulation.
This rule will not have substantial
direct effects on the states, on the
relationship between the national
government and the states, or on the
distribution of power and
responsibilities among the various
levels of government, as specified in
Executive Order 13132, because it
merely addresses the State not fully
meeting its obligation under the CAA to
include in its SIP provisions to meet the
visibility requirements of Part C of Title
I of the CAA and to prohibit emissions
from interfering with other states
measures to protect visibility. Thus,
Executive Order 13132 does not apply
to this action.
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F. Executive Order 13175: Consultation
and Coordination With Indian Tribal
Governments
Executive Order 13175, entitled
Consultation and Coordination with
Indian Tribal Governments (65 FR
67249, November 9, 2000), requires EPA
to develop an accountable process to
ensure ‘‘meaningful and timely input by
tribal officials in the development of
regulatory policies that have tribal
implications.’’ This final rule does not
have tribal implications, as specified in
Executive Order 13175. It will not have
substantial direct effects on tribal
governments. Thus, Executive Order
13175 does not apply to this rule.
when the Agency decides not to use
available and applicable voluntary
consensus standards.
This final rulemaking does not
involve technical standards. Therefore,
EPA is not considering the use of any
voluntary consensus standards.
H. Executive Order 13211: Actions
Concerning Regulations That
Significantly Affect Energy Supply,
Distribution, or Use
This action is not subject to Executive
Order 13211 (66 FR 28355 (May 22,
2001)), because it is not a significant
regulatory action under Executive Order
12866.
J. Executive Order 12898: Federal
Actions To Address Environmental
Justice in Minority Populations and
Low-Income Populations
Executive Order 12898 (59 FR 7629,
February 16, 1994), establishes federal
executive policy on environmental
justice. Its main provision directs
federal agencies, to the greatest extent
practicable and permitted by law, to
make environmental justice part of their
mission by identifying and addressing,
as appropriate, disproportionately high
and adverse human health or
environmental effects of their programs,
policies, and activities on minority
populations and low-income
populations in the United States.
We have determined that this final
action will not have disproportionately
high and adverse human health or
environmental effects on minority or
low-income populations because it
increases the level of environmental
protection for all affected populations
without having any disproportionately
high and adverse human health or
environmental effects on any
population, including any minority or
low-income population. This final rule
limits emissions of NOX from three
facilities and five BART units in
Wyoming. The partial approval of the
SIP merely approves state law as
meeting Federal requirements and
imposes no additional requirements
beyond those imposed by state law.
I. National Technology Transfer and
Advancement Act
Section 12(d) of the National
Technology Transfer and Advancement
Act of 1995 (‘‘NTTAA’’), Public Law
104–113, 12(d) (15 U.S.C. 272 note)
directs EPA to use voluntary consensus
standards in its regulatory activities
unless to do so would be inconsistent
with applicable law or otherwise
impractical. Voluntary consensus
standards are technical standards (e.g.,
materials specifications, test methods,
sampling procedures, and business
practices) that are developed or adopted
by voluntary consensus standards
bodies. NTTAA directs EPA to provide
Congress, through OMB, explanations
K. Congressional Review Act
The Congressional Review Act, 5
U.S.C 801 et seq., as added by the Small
Business Regulatory Enforcement
Fairness Act of 1996, generally provides
that before a rule may take effect, the
agency promulgating the rule must
submit a rule report, which includes a
copy of the rule, to each House of the
Congress and to the Comptroller General
of the United States. Section 804
exempts from section 801 the following
types of rules (1) rules of particular
applicability; (2) rules relating to agency
management or personnel; and (3) rules
of agency organization, procedure, or
practice that do not substantially affect
the rights or obligations of non-agency
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G. Executive Order 13045: Protection of
Children From Environmental Health
Risks and Safety Risks
EPA interprets EO 13045 (62 FR
19885, April 23, 1997) as applying only
to those regulatory actions that concern
health or safety risks, such that the
analysis required under section 5–501 of
the EO has the potential to influence the
regulation. This action is not subject to
EO 13045 because it implements
specific standards established by
Congress in statutes. However, to the
extent this final rule will limit
emissions of NOX and PM, the rule will
have a beneficial effect on children’s
health by reducing air pollution.
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5219
parties. 5 U.S. 804(3). EPA is not
required to submit a rule report
regarding today’s action under section
801 because this is a rule of particular
applicability. This rule finalizes a FIP
for three sources.
L. Judicial Review
Under section 307(b)(1) of the CAA,
petitions for judicial review of this
action must be filed in the United States
Court of Appeals for the appropriate
circuit by March 31, 2014. Pursuant to
CAA section 307(d)(1)(B), this action is
subject to the requirements of CAA
section 307(d) as it promulgates a FIP
under CAA section 110(c). Filing a
petition for reconsideration by the
Administrator of this final rule does not
affect the finality of this action for the
purposes of judicial review nor does it
extend the time within which a petition
for judicial review may be filed, and
shall not postpone the effectiveness of
such rule or action. This action may not
be challenged later in proceedings to
enforce its requirements. See CAA
section 307(b)(2).
List of Subjects in 40 CFR Part 52
Environmental protection, Air
pollution control, Incorporation by
reference, Intergovernmental relations,
Nitrogen dioxide, Particulate matter,
Reporting and recordkeeping
requirements, Sulfur oxides, Volatile
organic compounds.
Dated: January 10, 2014.
Gina McCarthy,
Administrator, U.S. EPA.
40 CFR part 52 is amended to read as
follows:
PART 52—APPROVAL AND
PROMULGATION OF
IMPLEMENTATION PLANS
1. The authority citation for part 52
continues to read as follows:
■
Authority: 42 U.S.C. 7401 et seq.
Subpart ZZ—Wyoming
2. Section 52.2620, in the table in
paragraph (e) is amended by adding an
entry for ‘‘XXIII. Wyoming State
Implementation Plan for Regional Haze
for 309(g)’’ at the end of the table.
■
§ 52.2620
*
Identification of plan.
*
*
(e) * * *
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*
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Name of nonregulatory SIP
provision
Applicable
geographic or
nonattainment
area
*
*
XXIII. Wyoming State Imple- Statewide ..........
mentation Plan for Regional Haze for 309(g).
3. Add § 52.2636 to subpart ZZ to read
as follows:
■
§ 52.2636
haze.
Implementation plan for regional
(a) Applicability. (1) This section
applies to each owner and operator of
the following emissions units in the
State of Wyoming for which EPA
approved the State’s BART
determination:
(i) FMC Westvaco Trona Plant Units
NS–1A and NS–1B (PM and NOX);
(ii) TATA Chemicals Partners
(previously General Chemical) Boilers C
and D (PM and NOX);
(iii) Basin Electric Power Cooperative
Laramie River Station Units 1, 2, and 3
(PM);
(iv) PacifiCorp Dave Johnston Power
Plant Unit 3 (PM);
(v) PacifiCorp Dave Johnston Power
Plant Unit 4 (PM and NOX);
(vi) PacifiCorp Jim Bridger Power
Plant Units 1, 2, 3, and 4 (PM and NOX);
(vii) PacifiCorp Naughton Power Plant
Units 1, 2, and 3 (PM and NOX); and
(viii) PacifiCorp Wyodak Power Plant
Unit 1 (PM).
(2) This section also applies to each
owner and operator of the following
State
submittal
date/adopted
date
EPA approval date
and citation 3
*
1/30/14, [Insert Federal Register
page number
where the document begins.].
*
Submitted:
1/12/2011
Explanations
*
*
*
Excluding portions of the following: Chapter 6.4, Chapter 6.5.5, Chapter 6.5.7, Chapter 6.5.8, and Chapter
7.5. We are excluding portions of these chapters because EPA disapproved: (1) The NOX BART determinations for: (1) Laramie River Units 1–3, Dave
Johnston Unit 3, and Wyodak Unit 1; (2) the State’s
monitoring, recordkeeping, and reporting requirements for BART units; (3) the State’s reasonable
progress goals.
emissions units in the State of Wyoming
for which EPA disapproved the State’s
BART determination and issued a NOX
BART Federal Implementation Plan:
(i) Basin Electric Power Cooperative
Laramie River Station Units 1, 2, and 3;
(ii) PacifiCorp Dave Johnston Unit 3;
and
(iii) PacifiCorp Wyodak Power Plant
Unit 1.
(b) Definitions. Terms not defined
below shall have the meaning given
them in the Clean Air Act or EPA’s
regulations implementing the Clean Air
Act. For purposes of this section:
(1) BART means Best Available
Retrofit Technology.
(2) BART unit means any unit subject
to a Regional Haze emission limit in
Table 1 and Table 2 of this section.
(3) CAM means Compliance
Assurance Monitoring as required by 40
CFR part 64.
(4) Continuous emission monitoring
system or CEMS means the equipment
required by this section to sample,
analyze, measure, and provide, by
means of readings recorded at least once
every 15 minutes (using an automated
data acquisition and handling system
(DAHS)), a permanent record of NOX
emissions, diluent, or stack gas
volumetric flow rate.
(5) FIP means Federal Implementation
Plan.
(6) The term lb/hr means pounds per
hour.
(7) The term lb/MMBtu means pounds
per million British thermal units of heat
input to the fuel-burning unit.
(8) NOX means nitrogen oxides.
(9) Operating day means a 24-hour
period between 12 midnight and the
following midnight during which any
fuel is combusted at any time in the
BART unit. It is not necessary for fuel
to be combusted for the entire 24-hour
period.
(10) The owner/operator means any
person who owns or who operates,
controls, or supervises a unit identified
in paragraph (a) of this section.
(11) PM means filterable total
particulate matter.
(12) Unit means any of the units
identified in paragraph (a) of this
section.
(c) Emissions limitations. (1) The
owners/operators of emissions units
subject to this section shall not emit, or
cause to be emitted, PM or NOX in
excess of the following limitations:
TABLE 1 TO § 52.2636
[Emission limits for BART units for which EPA approved the State’s BART and Reasonable Progress determinations]
PM emission
limits—lb/MMBtu
mstockstill on DSK4VPTVN1PROD with RULES2
Source name/BART unit
FMC Westvaco Trona Plant/Unit NS–1A ........................................................................................................
FMC Westvaco Trona Plant/Unit NS–1B ........................................................................................................
TATA Chemicals Partners (General Chemical) Green River Trona Plant/Boiler C ........................................
TATA Chemicals Partners (General Chemical) Green River Trona Plant/Boiler D ........................................
Basin Electric Power Cooperative Laramie River Station/Unit 1 ....................................................................
Basin Electric Power Cooperative Laramie River Station/Unit 2 ....................................................................
Basin Electric Power Cooperative Laramie River Station/Unit 3 ....................................................................
PacifiCorp Dave Johnston Power Plant/Unit 3 ................................................................................................
3 In order to determine the EPA effective date for
a specific provision listed in this table, consult the
VerDate Mar<15>2010
18:38 Jan 29, 2014
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Federal Register notice cited in this column for the
particular provision.
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E:\FR\FM\30JAR2.SGM
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0.05
0.05
0.09
0.09
0.03
0.03
0.03
0.015
NOX emission
limits—
lb/MMBtu
(30-day
rolling
average)
0.35
0.35
0.28
0.28
N/A
N/A
N/A
N/A
5221
Federal Register / Vol. 79, No. 20 / Thursday, January 30, 2014 / Rules and Regulations
TABLE 1 TO § 52.2636—Continued
[Emission limits for BART units for which EPA approved the State’s BART and Reasonable Progress determinations]
PM emission
limits—lb/MMBtu
Source name/BART unit
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
Dave Johnston Power Plant/Unit 4 ................................................................................................
Jim Bridger Power Plant/Unit 1 1 ...................................................................................................
Jim Bridger Power Plant/Unit 2 1 ...................................................................................................
Jim Bridger Power Plant/Unit 3 1 ...................................................................................................
Jim Bridger Power Plant/Unit 4 1 ...................................................................................................
Naughton Power Plant/Unit 1 ........................................................................................................
Naughton Power Plant/Unit 2 ........................................................................................................
Naughton Power Plant/Unit 3 ........................................................................................................
Wyodak Power Plant/Unit 1 ...........................................................................................................
NOX emission
limits—
lb/MMBtu
(30-day
rolling
average)
0.015
0.03
0.03
0.03
0.03
0.04
0.04
0.015
0.015
0.15
0.26/0.07
0.26/0.07
0.26/0.07
0.26/0.07
0.26
0.26
0.07
N/A
1 The owners and operators of PacifiCorp Jim Bridger Units 1, 2, 3, and 4 shall comply with the NO emission limit for BART of 0.26 lb/MMBtu
X
and PM emission limit for BART of 0.03 lb/MMBtu and other requirements of this section by March 4, 2019. The owners and operators of
PacifiCorp Jim Bridger Units 1, 2, 3 and 4 shall comply with the NOX emission limit for reasonable progress of 0.07 lb/MMBtu by: December 31,
2022 for Unit 1, December 31, 2021 for Unit 2, December 31, 2015, for Unit 3, and December 31, 2016, for Unit 4.
TABLE 2 TO § 52.2636
[Emission limits for BART units for which EPA disapproved the State’s BART determination and implemented a FIP]
NOX
emission
limit—lb/
MMBtu
(30-day
rolling
average)
Source name/BART unit
Basin Electric Power Cooperative Laramie River Station/Unit 1 ............................................................................................................
Basin Electric Power Cooperative Laramie River Station/Unit 2 ............................................................................................................
Basin Electric Power Cooperative Laramie River Station/Unit 3 ............................................................................................................
PacifiCorp Dave Johnston Unit 3 ............................................................................................................................................................
PacifiCorp Wyodak Power Plant/Unit 1 ...................................................................................................................................................
0.07
0.07
0.07
*0.07
0.07
mstockstill on DSK4VPTVN1PROD with RULES2
* (or 0.28 and shut-down-by December 31, 2027).
(2) These emission limitations shall
apply at all times, including startups,
shutdowns, emergencies, and
malfunctions.
(d) Compliance date. (1) The owners
and operators of PacifiCorp Jim Bridger
Units 1, 2, 3, and 4 shall comply with
the NOX emission limit of 0.26 lb/
MMBtu and PM emission limit of 0.03
lb/MMBtu and other requirements of
this section by March 4, 2019. The
owners and operators of PacifiCorp Jim
Bridger Units 1, 2, 3 and 4 shall comply
with the NOX emission limit of 0.07 lb/
MMBtu by: December 31, 2022 for Unit
1, December 31, 2021 for Unit 2,
December 31, 2015, for Unit 3, and
December 31, 2016, for Unit 4.
(2) The owners and operators of the
other BART sources subject to this
section shall comply with the emissions
limitations and other requirements of
this section by March 4, 2019.
(3) Compliance alternatives for
PacifiCorp Dave Johnston Unit 3. (i) The
owners and operators of PacifiCorp
Dave Johnston Unit 3 will meet a NOX
emission limit of 0.07 lb/MMBtu (30-
VerDate Mar<15>2010
18:38 Jan 29, 2014
Jkt 232001
day rolling average) by March 4, 2019;
or
(ii) Alternatively, the owners and
operators of PacifiCorp Dave Johnston
Unit 3 will permanently cease operation
of this unit on or before December 31,
2027.
(e) Compliance determinations for
NOX. (1) For all BART units other than
Trona Plant units:
(i) CEMS. At all times after the earliest
compliance date specified in paragraph
(d) of this section, the owner/operator of
each unit shall maintain, calibrate, and
operate a CEMS, in full compliance with
the requirements found at 40 CFR part
75, to accurately measure NOX, diluent,
and stack gas volumetric flow rate from
each unit. The CEMS shall be used to
determine compliance with the
emission limitations in paragraph (c) of
this section for each unit.
(ii) Method. (A) For any hour in
which fuel is combusted in a unit, the
owner/operator of each unit shall
calculate the hourly average NOX
emission rate in lb/MMBtu at the CEMS
in accordance with the requirements of
40 CFR part 75. At the end of each
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Fmt 4701
Sfmt 4700
operating day, the owner/operator shall
calculate and record a new 30-day
rolling average emission rate in lb/
MMBtu from the arithmetic average of
all valid hourly emission rates from the
CEMS for the current operating day and
the previous 29 successive operating
days.
(B) An hourly average NOX emission
rate in lb/MMBtu is valid only if the
minimum number of data points, as
specified in 40 CFR part 75, is acquired
by both the pollutant concentration
monitor (NOX) and the diluent monitor
(O2 or CO2).
(C) Data reported to meet the
requirements of this section shall not
include data substituted using the
missing data substitution procedures of
subpart D of 40 CFR part 75, nor shall
the data have been bias adjusted
according to the procedures of 40 CFR
part 75.
(2) For all Trona Plant BART units:
(i) CEMS. At all times after the
compliance date specified in paragraph
(d) of this section, the owner/operator of
each unit shall maintain, calibrate, and
operate a CEMS, in full compliance with
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mstockstill on DSK4VPTVN1PROD with RULES2
5222
Federal Register / Vol. 79, No. 20 / Thursday, January 30, 2014 / Rules and Regulations
the requirements found at 40 CFR part
60, to accurately measure NOX, diluent,
and stack gas volumetric flow rate from
each unit, including the CEMS quality
assurance requirements in appendix F
of 40 CFR part 60. The CEMS shall be
used to determine compliance with the
emission limitations in paragraph (c) of
this section for each unit.
(ii) Method. (A) For any hour in
which fuel is combusted in a unit, the
owner/operator of each unit shall
calculate the hourly average NOX
emission rate in lb/MMBtu at the CEMS
in accordance with the requirements of
40 CFR part 60. At the end of each
operating day, the owner/operator shall
calculate and record a new 30-day
rolling average emission rate in lb/
MMBtu from the arithmetic average of
all valid hourly emission rates from the
CEMS for the current operating day and
the previous 29 successive operating
days.
(B) An hourly average NOX emission
rate in lb/MMBtu is valid only if the
minimum number of data points, as
specified in 40 CFR part 60, is acquired
by both the pollutant concentration
monitor (NOX) and the diluent monitor
(O2 or CO2).
(f) Compliance determinations for
particulate matter. Compliance with the
particulate matter emission limit for
each BART unit shall be determined
from annual performance stack tests.
Within 60 days of the compliance
deadline specified in paragraph (d) of
this section, and on at least an annual
basis thereafter, the owner/operator of
each unit shall conduct a stack test on
each unit to measure particulate
emissions using EPA Method 5, 5B, 5D,
or 17, as appropriate, in 40 CFR part 60,
Appendix A. A test shall consist of three
runs, with each run at least 120 minutes
in duration and each run collecting a
minimum sample of 60 dry standard
cubic feet. Results shall be reported in
lb/MMBtu. In addition to annual stack
tests, the owner/operator shall monitor
particulate emissions for compliance
with the BART emission limits in
accordance with the applicable
Compliance Assurance Monitoring
(CAM) plan developed and approved by
the State in accordance with 40 CFR
part 64.
(g) Recordkeeping. The owner/
operator shall maintain the following
records for at least five years:
(1) All CEMS data, including the date,
place, and time of sampling or
measurement; parameters sampled or
measured; and results.
(2) Records of quality assurance and
quality control activities for emissions
VerDate Mar<15>2010
18:38 Jan 29, 2014
Jkt 232001
measuring systems including, but not
limited to, any records required by 40
CFR part 75. Or, for Trona Plant units,
records of quality assurance and quality
control activities for emissions
measuring systems including, but not
limited to appendix F of 40 CFR part 60.
(3) Records of all major maintenance
activities conducted on emission units,
air pollution control equipment, and
CEMS.
(4) Any other CEMS records required
by 40 CFR part 75. Or, for Trona Plant
units, any other CEMs records required
by 40 CFR part 60.
(5) Records of all particulate stack test
results.
(6) All data collected pursuant to the
CAM plan.
(h) Reporting. All reports under this
section shall be submitted to the
Director, Office of Enforcement,
Compliance and Environmental Justice,
U.S. Environmental Protection Agency,
Region 8, Mail Code 8ENF–AT, 1595
Wynkoop Street, Denver, Colorado
80202–1129.
(1) The owner/operator of each unit
shall submit quarterly excess emissions
reports for NOX BART units no later
than the 30th day following the end of
each calendar quarter. Excess emissions
means emissions that exceed the
emissions limits specified in paragraph
(c) of this section. The reports shall
include the magnitude, date(s), and
duration of each period of excess
emissions, specific identification of
each period of excess emissions that
occurs during startups, shutdowns, and
malfunctions of the unit, the nature and
cause of any malfunction (if known),
and the corrective action taken or
preventative measures adopted.
(2) The owner/operator of each unit
shall submit quarterly CEMS
performance reports, to include dates
and duration of each period during
which the CEMS was inoperative
(except for zero and span adjustments
and calibration checks), reason(s) why
the CEMS was inoperative and steps
taken to prevent recurrence, and any
CEMS repairs or adjustments. The
owner/operator of each unit shall also
submit results of any CEMS
performance tests required by 40 CFR
part 75. Or, for Trona Plant units, the
owner/operator of each unit shall also
submit results of any CEMs performance
test required appendix F of 40 CFR part
60 (Relative Accuracy Test Audits,
Relative Accuracy Audits, and Cylinder
Gas Audits).
(3) When no excess emissions have
occurred or the CEMS has not been
PO 00000
Frm 00192
Fmt 4701
Sfmt 9990
inoperative, repaired, or adjusted during
the reporting period, such information
shall be stated in the quarterly reports
required by paragraphs (h)(1) and (2) of
this section.
(4) The owner/operator of each unit
shall submit results of any particulate
matter stack tests conducted for
demonstrating compliance with the
particulate matter BART limits in
paragraphs (c) of this section, within 60
calendar days after completion of the
test.
(5) The owner/operator of each unit
shall submit semi-annual reports of any
excursions under the approved CAM
plan in accordance with the schedule
specified in the source’s title V permit.
(i) Notifications. (1) The owner/
operator shall promptly submit
notification of commencement of
construction of any equipment which is
being constructed to comply with the
NOX emission limits in paragraph (c) of
this section.
(2) The owner/operator shall
promptly submit semi-annual progress
reports on construction of any such
equipment.
(3) The owner/operator shall
promptly submit notification of initial
startup of any such equipment.
(j) Equipment operation. At all times,
the owner/operator shall maintain each
unit, including associated air pollution
control equipment, in a manner
consistent with good air pollution
control practices for minimizing
emissions.
(k) Credible evidence. Nothing in this
section shall preclude the use, including
the exclusive use, of any credible
evidence or information, relevant to
whether a source would have been in
compliance with requirements of this
section if the appropriate performance
or compliance test procedures or
method had been performed.
4. Add § 52.2637 to subpart ZZ to read
as follows:
■
§ 52.2637 Federal implementation plan for
reasonable attributable visibility impairment
long-term strategy.
As required by 40 CFR 41.306(c), EPA
will ensure that the review of the State’s
reasonably attributable visibility
impairment long-term strategy is
coordinated with the regional haze longterm strategy under 40 CFR 51.308(g).
EPA’s review will be in accordance with
the requirements of 40 CFR 51.306(c).
[FR Doc. 2014–00930 Filed 1–29–14; 8:45 am]
BILLING CODE 6560–50–P
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]]>Agencies
[Federal Register Volume 79, Number 20 (Thursday, January 30, 2014)]
[Rules and Regulations]
[Pages 5031-5222]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: 2014-00930]
[[Page 5031]]
Vol. 79
Thursday,
No. 20
January 30, 2014
Part II
Environmental Protection Agency
-----------------------------------------------------------------------
40 CFR Part 52
Approval, Disapproval and Promulgation of Implementation Plans; State
of Wyoming; Regional Haze State Implementation Plan; Federal
Implementation Plan for Regional Haze; Final Rule
Federal Register / Vol. 79 , No. 20 / Thursday, January 30, 2014 /
Rules and Regulations
[[Page 5032]]
-----------------------------------------------------------------------
ENVIRONMENTAL PROTECTION AGENCY
40 CFR Part 52
[EPA-R08-OAR-2012-0026, FRL9905-42-R08]
Approval, Disapproval and Promulgation of Implementation Plans;
State of Wyoming; Regional Haze State Implementation Plan; Federal
Implementation Plan for Regional Haze
AGENCY: Environmental Protection Agency.
ACTION: Final rule.
-----------------------------------------------------------------------
SUMMARY: The Environmental Protection Agency (EPA) is partially
approving and partially disapproving a State Implementation Plan (SIP)
submitted by the State of Wyoming on January 12, 2011, that addresses
regional haze. This SIP was submitted to address the requirements of
the Clean Air Act (CAA or ``the Act'') and rules that require states to
address in specific ways any existing anthropogenic impairment of
visibility in mandatory Class I areas caused by emissions of air
pollutants from numerous sources located over a wide geographic area
(also referred to as the ``regional haze program''). States are
required to assure reasonable progress toward the national goal of
achieving natural visibility conditions in Class I areas. EPA is
approving several aspects of Wyoming's regional haze SIP that we had
proposed to disapprove in our June 10, 2013 proposed rule in light of
public comments and newly available information indicating the adequacy
of the SIP with respect to those aspects. EPA is also approving some
aspects of the State's SIP that we proposed to approve. EPA is
promulgating a Federal Implementation Plan (FIP) to address some of the
deficiencies identified in our proposed partial disapproval of
Wyoming's regional haze SIP issued on June 10, 2013. EPA is taking this
action pursuant to sections 110 and 169A of the CAA.
DATES: This final rule is effective March 3, 2014.
ADDRESSES: EPA has established a docket for this action under Docket ID
No. EPA-R08-OAR-2012-0026. All documents in the docket are listed on
the www.regulations.gov Web site.
Publicly available docket materials are available either
electronically through www.regulations.gov, or in hard copy at the Air
Program, Environmental Protection Agency (EPA), Region 8, 1595 Wynkoop
Street, Denver, Colorado 80202-1129. EPA requests that if, at all
possible, you contact the individual listed in the FOR FURTHER
INFORMATION CONTACT section to view the hard copy of the docket. You
may view the hard copy of the docket Monday through Friday, 8 a.m. to 4
p.m., excluding Federal holidays.
FOR FURTHER INFORMATION CONTACT: Laurel Dygowski, Air Program, Mailcode
8P-AR, Environmental Protection Agency, Region 8, 1595 Wynkoop Street,
Denver, Colorado 80202-1129, (303) 312-6144, dygowski.laurel@epa.gov.
SUPPLEMENTARY INFORMATION:
Definitions
For the purpose of this document, we are giving meaning to certain
words or initials as follows:
i. The words or initials Act or CAA mean or refer to the Clean
Air Act, unless the context indicates otherwise.
ii. The initials AFUDC mean or refer to Allowance for Funds
Utilized During Construction.
iii. The initials APA mean or refer to the Administrative
Procedures Act.
iv. The initials AQRV mean or refer to Air Quality Related
Value.
v. The initials BACT mean or refer to Best Available Control
Technology.
vi. The initials BART mean or refer to Best Available Retrofit
Technology.
vii. The initials CAMD mean or refer to Clean Air Markets
Division.
viii. The initials CAMx mean or refer to Comprehensive Air
Quality Model.
ix. The initials CCM mean or refer to EPA's Control Cost Manual.
x. The initials CLRC mean or refer to the Construction Labor
Research Council.
xi. The initials CMAQ mean or refer to Community Multi-Scale Air
Quality modeling system.
xii. The initials CSAPR mean or refer to the Cross-State Air
Pollution Rule.
xiii. The initial DEQ mean or refer to the Wyoming Department of
Environmental Quality.
xiv. The initials EGUs mean or refer to Electric Generating
Units.
xv. The initials EIS mean or refer to Environmental Impact
Statement.
xvi. The words EPA, we, us or our mean or refer to the United
States Environmental Protection Agency.
xvii. The initials ESP mean or refer to electrostatic
precipitator.
xviii. The initials FIP mean or refer to Federal Implementation
Plan.
xix. The initials FLM mean or refer to Federal Land Managers.
xx. The initials FR mean or refer to the Federal Register.
xxi. The initials GAQM mean or refer to Guidance on Air Quality
Models.
xxii. The initials IMPROVE mean or refer to Interagency
Monitoring of Protected Visual Environments monitoring network.
xxiii. The initials IPM mean or refer to Integrated Planning
Model.
xxiv. The initials IWAQM mean or refer to Interagency Workgroup
on Air Quality Modeling.
xxv. The initials LNB mean or refer to low NOX
burners.
xxvi. The initials LRS mean or refer to Laramie River Station.
xxvii. The initials LTS mean or refer to long term strategy.
xxviii. The initials MATS mean or refer to the Mercury and Air
Toxics Standard.
xxix. The initials MW mean or refer to megawatts.
xxx. The initials NAAQS mean or refer to National Ambient Air
Quality Standards.
xxxi. The initials NEPA mean or refer to National Environmental
Policy Act.
xxxii. The initials NH 3 mean or refer to ammonia.
xxxiii. The initials NO X mean or refer to nitrogen
oxides.
xxxiv. The initials OFA mean or refer to overfire air.
xxxv. The initials PM mean or refer to particulate matter.
xxxvi. The initials PM 2.5 mean or refer to
particulate matter with an aerodynamic diameter of less than 2.5
micrometers.
xxxvii. The initials PM 10 mean or refer to
particulate matter with an aerodynamic diameter of less than 10
micrometers.
xxxviii. The initials PTE mean or refer to potential to emit.
xxxix. The initials RAVI mean or refer to reasonably
attributable visibility impairment.
xl. The initials RHR mean or refer to the Regional Haze Rule.
xli. The initials RIS mean or refer to Regulatory Impact
Statement.
xlii. The initials RPG mean or refer to reasonable progress
goals.
xliii. The initials RPO mean or refer to Regional Planning
Organization.
xliv. The initials SCR mean or refer to selective catalytic
reduction.
xlv. The initials SIP mean or refer to State Implementation
Plan.
xlvi. The initials SNCR mean or refer to selective non-catalytic
reduction.
xlvii. The initials SO 2 mean or refer to sulfur
dioxide.
xlviii. The initials SOFA mean or refer to separated overfire
air.
xlix. The initials UMRA mean or refer to the Unfunded Mandates
Reform Act.
l. The initials URP mean or refer to Uniform Rate of Progress.
li. The initials VOC mean or refer to volatile organic
compounds.
lii. The initials WAQSR mean or refer to the Wyoming Air Quality
Standards and Regulations.
liii. The initials WRAP mean or refer to the Western Regional
Air Partnership.
liv. The words Wyoming and State mean the State of Wyoming.
Table of Contents
I. Background
A. Regional Haze
i. Requirements of the CAA and EPA's Regional Haze Rule (RHR)
ii. Roles of Agencies in Addressing Regional Haze
B. Requirements for the Regional Haze SIPs
i. The CAA and the Regional Haze Rule
ii. Determination of Baseline, Natural, and Current Visibility
Conditions
iii. Determination of Reasonable Progress Goals
[[Page 5033]]
iv. Best Available Retrofit Technology
v. Long-Term Strategy
vi. Coordinating Regional Haze and Reasonably Attributable
Visibility Impairment
vii. Monitoring Strategy and Other Implementation Plan
Requirements
viii. Consultation With States and Federal Land Managers (FLMs)
C. Our Proposal
D. Public Participation
II. Final Action
III. Changes From Proposed Rule and Reasons for Changes
A. Changes to Proposed Costs and Visibility Improvements
B. Changes to Our Proposed Determinations
1. Dave Johnston Unit 3
2. Dave Johnston Unit 4
3. Naughton Units 1 and 2
4. Naughton Unit 3
5. Wyodak
6. Jim Bridger
7. Dave Johnston Units 1 and 2
IV. Basis for Our Final Action
A. Laramie River
B. Jim Bridger
C. Dave Johnston Units 3 and 4
D. Naughton
E. Wyodak
F. Dave Johnston Units 1 and 2 (Reasonable Progress)
V. Issues Raised by Commenters and EPA's Responses
A. Legal Issues
1. EPA Authority and State Discretion
2. Compliance With Section 307(d)
3. Compliance With Section 169A(d)
4. Public Hearings
5. RHR and BART Guidelines
6. Reasonableness Standard
7. Reliance on Emission Reductions
8. Presumptive Limits
9. Compliance With 40 CFR 51.308
10. Legal Analysis
11. Consideration of Existing Controls
12. Consent Decree
13. Monitoring, Recordkeeping and Reporting
B. Modeling
1. General Comments
2. EPA Modeling
a. Description of Revised EPA Modeling
b. Comments on EPA Modeling
C. Overarching Comments on BART
1. BART-Eligible Sources
2. Cost of Controls
3. Consideration of the Five Factors
4. Visibility Improvement
5. PM BART Determinations
6. Incremental Costs and Visibility
7. Other Comments on BART
D. BART Sources
1. Basin Electric Laramie River Station Units 1-3
a. General Comments
b. NOX BART Determination
2. Jim Bridger Units 1-4
a. NOX BART Determination
b. PM BART Determination
3. Dave Johnston Unit 3 and Unit 4
a. NOX BART Determination
b. Alternative Control Technology Proposal
4. Naughton Units 1-3
a. NOX BART Determination
b. Alternative Control Technology Proposal
5. Wyodak
6. Trona Mines
a. FMC Westvaco and General Chemical Green River
b. FMC Granger Trona Mine
E. Reasonable Progress
1. RPGs
2. Reasonable Progress Sources
a. Oil and Gas Sources
b. Dave Johnston Unit 1 and Unit 2
F. General Comments
1. Replacement of FIP Elements With SIP
2. Public Comment
3. Economic Concerns
4. National Ambient Air Quality Standards (NAAQS)
5. Other
VI. Non-Relevant Comments From EPA's Original June 4, 2012 Proposal
A. General Comments
B. Basin Electric Laramie River
C. Jim Bridger Units 1-4
D. Dave Johnston Units 3 and 4
E. Naughton Units 1-3
F. Wyodak
G. Dave Johnston Units 1 and 2
H. Modeling
VII. Statutory and Executive Order Reviews
I. Background
The CAA requires each state to develop plans, referred to as SIPs,
to meet various air quality requirements. A state must submit its SIP
and SIP revisions to us for approval. Once approved, a SIP is
enforceable by EPA and citizens under the CAA, also known as being
federally enforceable. If a state fails to make a required SIP
submittal or if we find that a state's required submittal is incomplete
or unapprovable, then we must promulgate a FIP to fill this regulatory
gap. CAA section 110(c)(1). This action involves the requirement that
states have SIPs that address regional haze.
Few states submitted a regional haze SIP prior to the December 17,
2007 deadline, and on January 15, 2009, EPA found that 37 states,
including Wyoming,\1\ the District of Columbia, and the Virgin Islands,
had failed to submit SIPs addressing the regional haze requirements. 74
FR 2392. Once EPA has found that a state has failed to make a required
submission, EPA is required to promulgate a FIP within two years unless
the state submits a SIP and the Agency approves it within the two-year
period. CAA section 110(c)(1). Wyoming subsequently submitted a SIP
addressing regional haze on January 12, 2011.
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\1\ We issued a finding of failure to submit for Wyoming only
for the requirements of 40 CFR 51.309(g)) regarding required SIP
provisions, including NOX BART, to address visibility at
Class I areas other than the 16 areas covered by the Grand Canyon
Visibility Transport Commission Report. Wyoming had submitted a SIP
for the rest of the requirements under 40 CFR 51.309 prior to our
January 15, 2009 finding.
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States in the west were given the option to meet the requirements
of the RHR either under 40 CFR 51.309 or 40 CFR 51.308. Wyoming chose
to adopt the requirements of 40 CFR 51.309. Section 309 requires states
to adopt regional haze strategies that are based on recommendations
from the Grand Canyon Visibility Transport Commission for protecting
the 16 Class I areas in the Colorado Plateau area, including a sulfur
dioxide (SO2) backstop cap and trade program, SO2
milestones, and other requirements such as smoke management, a program
to address mobile sources, and pollution prevention. Also, section
309(g) includes requirements for SIP provisions, including
NOX BART, to address visibility impairment at other Class I
areas. On December 12, 2012, we finalized approval of Wyoming's 309
regional haze SIP for the requirements relating to the SO2
backstop cap and trade program, milestones and the other
requirements.\2\ Today's action addresses the remaining portion of
Wyoming's SIP, including the Best Available Retrofit Technology (BART)
determinations for nitrogen oxides (NOX) and particulate
matter (PM).
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\2\ 77 FR 73926 (Dec. 12, 2012).
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In a lawsuit in the U.S. District Court for the District of
Colorado, environmental groups sued EPA for our failure to take timely
action with respect to the regional haze requirements of the CAA and
our regulations.\3\ In particular, the lawsuits alleged that we had
failed to promulgate FIPs for these requirements within the two-year
period allowed by CAA section 110(c) or, in the alternative, fully
approve SIPs addressing these requirements.
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\3\ WildEarth Guardians v. Jackson, 1:11-cv-CMA-MEH (D. Colo.).
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As a result of these lawsuits, we entered into a consent decree.
The consent decree requires that we sign a notice of final rulemaking
addressing the regional haze requirements for Wyoming by January 10,
2014.\4\ We are meeting that requirement with the signing of this final
rule
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\4\ WildEarth Guardians v. Jackson, 1:11-cv-CMA-MEH (D. Colo.)
(Dkt. Nos. 73, 74).
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A. Regional Haze
Regional haze is visibility impairment that is produced by a
multitude of sources and activities which are located across a broad
geographic area and emit fine particles (PM2.5) (e.g.,
sulfates, nitrates, organic carbon (OC), elemental carbon (EC), and
soil dust), and their precursors (e.g., sulfur dioxide
(SO2),
[[Page 5034]]
NOX, and in some cases, ammonia (NH3) and
volatile organic compounds (VOC)). Fine particle precursors react in
the atmosphere to form PM2.5, which impairs visibility by
scattering and absorbing light. Visibility impairment reduces the
clarity, color, and visible distance that one can see. PM2.5
can also cause serious health effects and mortality in humans and
contributes to environmental effects such as acid deposition and
eutrophication.
Data from the existing visibility monitoring network, the
``Interagency Monitoring of Protected Visual Environments'' (IMPROVE)
monitoring network, show that visibility impairment caused by air
pollution occurs virtually all the time at most national park and
wilderness areas. The average visual range \5\ in many Class I areas
(i.e., national parks and memorial parks, wilderness areas, and
international parks meeting certain size criteria) in the western
United States is 100-150 kilometers, or about one-half to two-thirds of
the visual range that would exist without anthropogenic air pollution.
In most of the eastern Class I areas of the United States, the average
visual range is less than 30 kilometers, or about one-fifth of the
visual range that would exist under estimated natural conditions. 64 FR
35715 (July 1, 1999).
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\5\ Visual range is the greatest distance, in kilometers or
miles, at which a dark object can be viewed against the sky.
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i. Requirements of the CAA and EPA's Regional Haze Rule (RHR)
In section 169A of the 1977 Amendments to the CAA, Congress created
a program for protecting visibility in the nation's national parks and
wilderness areas. This section of the CAA establishes as a national
goal the ``prevention of any future, and the remedying of any existing,
impairment of visibility in mandatory Class I Federal areas \6\ which
impairment results from manmade air pollution.'' On December 2, 1980,
EPA promulgated regulations to address visibility impairment in Class I
areas that is ``reasonably attributable'' to a single source or small
group of sources, i.e., ``reasonably attributable visibility
impairment.'' 45 FR 80084. These regulations represented the first
phase in addressing visibility impairment. EPA deferred action on
regional haze that emanates from a variety of sources until monitoring,
modeling and scientific knowledge about the relationships between
pollutants and visibility impairment were improved.
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\6\ Areas designated as mandatory Class I Federal areas consist
of national parks exceeding 6000 acres, wilderness areas and
national memorial parks exceeding 5000 acres, and all international
parks that were in existence on August 7, 1977. 42 U.S.C. 7472(a).
In accordance with section 169A of the CAA, EPA, in consultation
with the Department of Interior, promulgated a list of 156 areas
where visibility is identified as an important value. 44 FR 69122
(November 30, 1979). The extent of a mandatory Class I area includes
subsequent changes in boundaries, such as park expansions. 42 U.S.C.
7472(a). Although states and tribes may designate as Class I
additional areas which they consider to have visibility as an
important value, the requirements of the visibility program set
forth in section 169A of the CAA apply only to ``mandatory Class I
Federal areas.'' Each mandatory Class I Federal area is the
responsibility of a ``Federal Land Manager.'' 42 U.S.C. 7602(i).
When we use the term ``Class I area'' in this action, we mean a
``mandatory Class I Federal area.''
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Congress added section 169B to the CAA in 1990 to address regional
haze issues. EPA promulgated a rule to address regional haze on July 1,
1999. 64 FR 35714 (July 1, 1999), codified at 40 CFR part 51, subpart
P. The RHR revised the existing visibility regulations to integrate
into the regulation provisions addressing regional haze impairment and
established a comprehensive visibility protection program for Class I
areas. The requirements for regional haze, found at 40 CFR 51.308 and
51.309, are included in EPA's visibility protection regulations at 40
CFR 51.300-51.309. Some of the main elements of the regional haze
requirements are summarized in section III of this preamble. The
requirement to submit a regional haze SIP applies to all 50 states, the
District of Columbia and the Virgin Islands. 40 CFR 51.308(b) requires
states to submit the first implementation plan addressing regional haze
visibility impairment no later than December 17, 2007.\7\
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\7\ EPA's regional haze regulations require subsequent updates
to the regional haze SIPs. 40 CFR 51.308(g)-(i).
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Few states submitted a regional haze SIP prior to the December 17,
2007 deadline, and on January 15, 2009, EPA found that 37 states
(including Wyoming), the District of Columbia, and the Virgin Islands,
had failed to submit SIPs addressing the regional haze requirements. 74
FR 2392. Once EPA has found that a state has failed to make a required
submission, EPA is required to promulgate a FIP within two years unless
the state submits a SIP and the Agency approves it within the two-year
period. CAA section110(c)(1).
ii. Roles of Agencies in Addressing Regional Haze
Successful implementation of the regional haze program will require
long-term regional coordination among states, tribal governments, and
various federal agencies. As noted above, pollution affecting the air
quality in Class I areas can be transported over long distances, even
hundreds of kilometers. Therefore, to effectively address the problem
of visibility impairment in Class I areas, states need to develop
strategies in coordination with one another, taking into account the
effect of emissions from one jurisdiction on the air quality in
another.
Because the pollutants that lead to regional haze can originate
from sources located across broad geographic areas, EPA has encouraged
the states and tribes across the United States to address visibility
impairment from a regional perspective. Five regional planning
organizations (RPOs) were developed to address regional haze and
related issues. The RPOs first evaluated technical information to
better understand how their states and tribes impact Class I areas
across the country, and then pursued the development of regional
strategies to reduce emissions of pollutants that lead to regional
haze.
The Western Regional Air Partnership (WRAP) RPO is a collaborative
effort of state governments, tribal governments, and various federal
agencies established to initiate and coordinate activities associated
with the management of regional haze, visibility and other air quality
issues in the western United States. WRAP member state governments
include: Alaska, Arizona, California, Colorado, Idaho, Montana, New
Mexico, North Dakota, Oregon, South Dakota, Utah, Washington, and
Wyoming. Tribal members include Campo Band of Kumeyaay Indians,
Confederated Salish and Kootenai Tribes, Cortina Indian Rancheria, Hopi
Tribe, Hualapai Nation of the Grand Canyon, Native Village of Shungnak,
Nez Perce Tribe, Northern Cheyenne Tribe, Pueblo of Acoma, Pueblo of
San Felipe, and Shoshone-Bannock Tribes of Fort Hall.
B. Requirements for Regional Haze SIPs
The following is a summary of the requirements of the RHR. See 40
CFR 51.308 for further detail regarding the requirements of the rule.
i. The CAA and the Regional Haze Rule
Regional haze SIPs must assure reasonable progress towards the
national goal of achieving natural visibility conditions in Class I
areas. Section 169A of the CAA and EPA's implementing regulations
require states to establish long-term strategies for making reasonable
progress toward meeting this goal. Implementation plans must also give
specific attention to certain stationary sources that were in
[[Page 5035]]
existence on August 7, 1977, but were not in operation before August 7,
1962, and require these sources, where appropriate, to install BART
controls for the purpose of eliminating or reducing visibility
impairment. The specific regional haze SIP requirements are discussed
in further detail below.
ii. Determination of Baseline, Natural, and Current Visibility
Conditions
The RHR establishes the deciview as the principal metric or unit
for expressing visibility. See 70 FR 39104, 39118. This visibility
metric expresses uniform changes in the degree of haze in terms of
common increments across the entire range of visibility conditions,
from pristine to extremely hazy conditions. Visibility expressed in
deciviews is determined by using air quality measurements to estimate
light extinction and then transforming the value of light extinction
using a logarithmic function. The deciview is a more useful measure for
tracking progress in improving visibility than light extinction itself
because each deciview change is an equal incremental change in
visibility perceived by the human eye. Most people can detect a change
in visibility at one deciview.\8\
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\8\ The preamble to the RHR provides additional details about
the deciview. 64 FR 35714, 35725 (July 1, 1999).
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The deciview is used in expressing RPGs (which are interim
visibility goals towards meeting the national visibility goal),
defining baseline, current, and natural conditions, and tracking
changes in visibility. The regional haze SIPs must contain measures
that ensure ``reasonable progress'' toward the national goal of
preventing and remedying visibility impairment in Class I areas caused
by anthropogenic air pollution by reducing anthropogenic emissions that
cause regional haze. The national goal is a return to natural
conditions, i.e., anthropogenic sources of air pollution would no
longer impair visibility in Class I areas.
To track changes in visibility over time at each of the 156 Class I
areas covered by the visibility program (40 CFR 81.401-437), and as
part of the process for determining reasonable progress, states must
calculate the degree of existing visibility impairment at each Class I
area at the time of each regional haze SIP submittal and periodically
review progress every five years midway through each 10-year
implementation period. To do this, the RHR requires states to determine
the degree of impairment (in deciviews) for the average of the 20
percent least impaired (``best'') and 20 percent most impaired
(``worst'') visibility days over a specified time period at each of
their Class I areas. In addition, states must also develop an estimate
of natural visibility conditions for the purpose of comparing progress
toward the national goal. Natural visibility is determined by
estimating the natural concentrations of pollutants that cause
visibility impairment and then calculating total light extinction based
on those estimates. We have provided guidance to states regarding how
to calculate baseline, natural and current visibility conditions.\9\
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\9\ Guidance for Estimating Natural Visibility Conditions Under
the Regional Haze Rule, September 2003, EPA-454/B-03-005, available
at https://www.epa.gov/ttncaaa1/t1/memoranda/Regional_Haze_envcurhr_gd.pdf, (hereinafter referred to as ``our 2003 Natural
Visibility Guidance''); and Guidance for Tracking Progress Under the
Regional Haze Rule, (September 2003, EPA-454/B-03-004, available at
https://www.epa.gov/ttncaaa1/t1/memoranda/rh_tpurhr_gd.pdf,
(hereinafter referred to as our ``2003 Tracking Progress
Guidance'').
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For the first regional haze SIPs that were due by December 17,
2007, ``baseline visibility conditions'' were the starting points for
assessing ``current'' visibility impairment. Baseline visibility
conditions represent the degree of visibility impairment for the 20
percent least impaired days and 20 percent most impaired days for each
calendar year from 2000 to 2004. Using monitoring data for 2000 through
2004, states are required to calculate the average degree of visibility
impairment for each Class I area, based on the average of annual values
over the five-year period. The comparison of initial baseline
visibility conditions to natural visibility conditions indicates the
amount of improvement necessary to attain natural visibility, while the
future comparison of baseline conditions to the then current conditions
will indicate the amount of progress made. In general, the 2000-2004
baseline period is considered the time from which improvement in
visibility is measured.
iii. Determination of Reasonable Progress Goals
The vehicle for ensuring continuing progress towards achieving the
natural visibility goal is the submission of a series of regional haze
SIPs from the states that establish two RPGs (i.e., two distinct goals,
one for the ``best'' and one for the ``worst'' days) for every Class I
area for each (approximately) 10-year implementation period. See 40 CFR
51.308(d), (f). The RHR does not mandate specific milestones or rates
of progress, but instead calls for states to establish goals that
provide for ``reasonable progress'' toward achieving natural visibility
conditions. In setting RPGs, states must provide for an improvement in
visibility for the most impaired days over the (approximately) 10-year
period of the SIP, and ensure no degradation in visibility for the
least impaired days over the same period. Id.
In establishing RPGs, states are required to consider the following
factors established in section 169A of the CAA and in our RHR at 40 CFR
51.308(d)(1)(i)(A): (1) The costs of compliance; (2) the time necessary
for compliance; (3) the energy and non-air quality environmental
impacts of compliance; and (4) the remaining useful life of any
potentially affected sources. States must demonstrate in their SIPs how
these factors are considered when selecting the RPGs for the best and
worst days for each applicable Class I area. In setting the RPGs,
states must also consider the rate of progress needed to reach natural
visibility conditions by 2064 (referred to as the ``uniform rate of
progress'' (URP) or the ``glidepath'') and the emission reduction
measures needed to achieve that rate of progress over the 10-year
period of the SIP. Uniform progress towards achievement of natural
conditions by the year 2064 represents a rate of progress, which states
are to use for analytical comparison to the amount of progress they
expect to achieve. In setting RPGs, each state with one or more Class I
areas (``Class I state'') must also consult with potentially
``contributing states,'' i.e., other nearby states with emission
sources that may be affecting visibility impairment at the state's
Class I areas. 40 CFR 51.308(d)(1)(iv). In determining whether a
state's goals for visibility improvement provide for reasonable
progress toward natural visibility conditions, EPA is required to
evaluate the demonstrations developed by the state pursuant to
paragraphs 40 CFR 51.308(d)(1)(i) and (d)(1)(ii). 40 CFR
51.308(d)(1)(iii).
iv. Best Available Retrofit Technology
Section 169A of the CAA directs states to evaluate the use of
retrofit controls at certain larger, often uncontrolled, older
stationary sources in order to address visibility impacts from these
sources. Specifically, section 169A(b)(2)(A) of the CAA requires states
to revise their SIPs to contain such measures as may be necessary to
make reasonable progress towards the natural visibility goal, including
a requirement that certain categories of existing major
[[Page 5036]]
stationary sources\10\ built between 1962 and 1977 procure, install,
and operate the ``Best Available Retrofit Technology'' as determined by
the state. Under the RHR, states are directed to conduct BART
determinations for such ``BART-eligible'' sources that may be
anticipated to cause or contribute to any visibility impairment in a
Class I area. Rather than requiring source-specific BART controls,
states also have the flexibility to adopt an emissions trading program
or other alternative program as long as the alternative provides
greater reasonable progress towards improving visibility than BART.
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\10\ The set of ``major stationary sources'' potentially
subject-to-BART is listed in CAA section 169A(g)(7).
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On July 6, 2005, EPA published the Guidelines for BART
Determinations Under the Regional Haze Rule at appendix Y to 40 CFR
part 51 (hereinafter referred to as the ``BART Guidelines'') to assist
states in determining which of their sources should be subject to the
BART requirements and in determining appropriate emission limits for
each applicable source. 70 FR 39104. In making a BART determination for
a fossil fuel-fired electric generating plant with a total generating
capacity in excess of 750 megawatts (MW), a state must use the approach
set forth in the BART Guidelines. Generally, a state is encouraged, but
not required, to follow the BART Guidelines in making BART
determinations for other types of sources. Regardless of source size or
type, a state must meet the requirements of the CAA and our regulations
for selection of BART, and the state's BART analysis and determination
must be reasonable in light of the overarching purpose of the regional
haze program.
The process of establishing BART emission limitations can be
logically broken down into three steps: First, states identify those
sources which meet the definition of ``BART-eligible source'' set forth
in 40 CFR 51.301; \11\ second, states determine which of such sources
``emits any air pollutant which may reasonably be anticipated to cause
or contribute to any impairment of visibility in any such area'' (a
source which fits this description is ``subject to BART''); and third,
for each source subject-to-BART, states then identify the best
available type and level of control for reducing emissions.
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\11\ BART-eligible sources are those sources that have the
potential to emit 250 tons or more of a visibility-impairing air
pollutant, were not in operation prior to August 7, 1962, but were
in existence on August 7, 1977, and whose operations fall within one
or more of 26 specifically listed source categories. 40 CFR 51.301.
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States must address all visibility-impairing pollutants emitted by
a source in the BART determination process. The most significant
visibility impairing pollutants are SO2, NOX, and
PM. EPA has stated that states should use their best judgment in
determining whether VOC or NH3 emissions impair visibility
in Class I areas.
Under the BART Guidelines, states may select an exemption threshold
value for their BART modeling, below which a BART-eligible source would
not be expected to cause or contribute to visibility impairment in any
Class I area. The state must document this exemption threshold value in
the SIP and must state the basis for its selection of that value. Any
source with emissions that model above the threshold value would be
subject to a BART determination review. The BART Guidelines acknowledge
varying circumstances affecting different Class I areas. States should
consider the number of emission sources affecting the Class I areas at
issue and the magnitude of the individual sources' impacts. Any
exemption threshold set by the state should not be higher than 0.5
deciview. 40 CFR part 51, appendix Y, section III.A.1.
In their SIPs, states must identify the sources that are subject-
to-BART and document their BART control determination analyses for such
sources. In making their BART determinations, section 169A(g)(2) of the
CAA requires that states consider the following factors when evaluating
potential control technologies: (1) The costs of compliance; (2) the
energy and non-air quality environmental impacts of compliance; (3) any
existing pollution control technology in use at the source; (4) the
remaining useful life of the source; and (5) the degree of improvement
in visibility which may reasonably be anticipated to result from the
use of such technology.
A regional haze SIP must include source-specific BART emission
limits and compliance schedules for each source subject-to-BART. Once a
state has made its BART determination, the BART controls must be
installed and in operation as expeditiously as practicable, but no
later than five years after the date of EPA approval of the regional
haze SIP. CAA section 169(g)(4) and 40 CFR 51.308(e)(1)(iv). In
addition to what is required by the RHR, general SIP requirements
mandate that the SIP must also include all regulatory requirements
related to monitoring, recordkeeping, and reporting for the BART
controls on the source. See e.g. CAA section 110(a). As noted above,
the RHR allows states to implement an alternative program in lieu of
BART so long as the alternative program can be demonstrated to achieve
greater reasonable progress toward the national visibility goal than
would BART.
v. Long-Term Strategy
Consistent with the requirement in section 169A(b) of the CAA that
states include in their regional haze SIP a 10 to 15-year strategy for
making reasonable progress, section 51.308(d)(3) of the RHR requires
that states include a LTS in their regional haze SIPs. The LTS is the
compilation of all control measures a state will use during the
implementation period of the specific SIP submittal to meet applicable
RPGs. The LTS must include ``enforceable emissions limitations,
compliance schedules, and other measures as necessary to achieve the
reasonable progress goals'' for all Class I areas within, or affected
by emissions from, the state. 40 CFR 51.308(d)(3).
When a state's emissions are reasonably anticipated to cause or
contribute to visibility impairment in a Class I area located in
another state, the RHR requires the impacted state to coordinate with
the contributing states in order to develop coordinated emissions
management strategies. 40 CFR 51.308(d)(3)(i). In such cases, the
contributing state must demonstrate that it has included, in its SIP,
all measures necessary to obtain its share of the emission reductions
needed to meet the RPGs for the Class I area. Id. at (d)(3)(ii). The
RPOs have provided forums for significant interstate consultation, but
additional consultations between states may be required to sufficiently
address interstate visibility issues. This is especially true where two
states belong to different RPOs.
States should consider all types of anthropogenic sources of
visibility impairment in developing their long-term strategy, including
stationary, minor, mobile, and area sources. At a minimum, states must
describe how each of the following seven factors listed below are taken
into account in developing their LTS: (1) Emission reductions due to
ongoing air pollution control programs, including measures to address
RAVI; (2) measures to mitigate the impacts of construction activities;
(3) emissions limitations and schedules for compliance to achieve the
RPG; (4) source retirement and replacement schedules; (5) smoke
management techniques for agricultural and forestry management purposes
including plans as currently exist within the state for these purposes;
(6) enforceability of emissions limitations and control measures; and
(7) the anticipated net
[[Page 5037]]
effect on visibility due to projected changes in point, area, and
mobile source emissions over the period addressed by the LTS. 40 CFR
51.308(d)(3)(v).
vi. Coordinating Regional Haze and Reasonably Attributable Visibility
Impairment
As part of the RHR, EPA revised 40 CFR 51.306(c) regarding the LTS
for RAVI to require that the RAVI plan must provide for a periodic
review and SIP revision not less frequently than every three years
until the date of submission of the state's first plan addressing
regional haze visibility impairment, which was due December 17, 2007,
in accordance with 40 CFR 51.308(b) and (c). On or before this date,
the state must revise its plan to provide for review and revision of a
coordinated LTS for addressing RAVI and regional haze, and the state
must submit the first such coordinated LTS with its first regional haze
SIP. Future coordinated LTS's, and periodic progress reports evaluating
progress towards RPGs, must be submitted consistent with the schedule
for SIP submission and periodic progress reports set forth in 40 CFR
51.308(f) and 51.308(g), respectively. The periodic review of a state's
LTS must report on both regional haze and RAVI impairment and must be
submitted to EPA as a SIP revision.
vii. Monitoring Strategy and Other Implementation Plan Requirements
Section 51.308(d)(4) of the RHR includes the requirement for a
monitoring strategy for measuring, characterizing, and reporting of
regional haze visibility impairment that is representative of all
mandatory Class I Federal areas within the state. The strategy must be
coordinated with the monitoring strategy required in section 51.305 for
RAVI. Compliance with this requirement may be met through
``participation'' in the IMPROVE network, i.e., review and use of
monitoring data from the network. The monitoring strategy is due with
the first regional haze SIP, and it must be reviewed every five years.
The monitoring strategy must also provide for additional monitoring
sites if the IMPROVE network is not sufficient to determine whether
RPGs will be met.
The SIP must also provide for the following:
Procedures for using monitoring data and other information
in a state with mandatory Class I areas to determine the contribution
of emissions from within the state to regional haze visibility
impairment at Class I areas both within and outside the state;
Procedures for using monitoring data and other information
in a state with no mandatory Class I areas to determine the
contribution of emissions from within the state to regional haze
visibility impairment at Class I areas in other states;
Reporting of all visibility monitoring data to the
Administrator at least annually for each Class I area in the state, and
where possible, in electronic format;
Developing a statewide inventory of emissions of
pollutants that are reasonably anticipated to cause or contribute to
visibility impairment in any Class I area. The inventory must include
emissions for a baseline year, emissions for the most recent year for
which data are available, and estimates of future projected emissions.
A state must also make a commitment to update the inventory
periodically; and
Other elements, including reporting, recordkeeping, and
other measures necessary to assess and report on visibility.
The RHR requires control strategies to cover an initial
implementation period extending to the year 2018, with a comprehensive
reassessment and revision of those strategies, as appropriate, every 10
years thereafter. Periodic SIP revisions must meet the core
requirements of section 51.308(d) with the exception of BART. The
requirement to evaluate sources for BART applies only to the first
regional haze SIP. Facilities subject-to-BART must continue to comply
with the BART provisions of section 51.308(e), as noted above. Periodic
SIP revisions will assure that the statutory requirement of reasonable
progress will continue to be met.
viii. Consultation With States and Federal Land Managers (FLMs)
The RHR requires that states consult with FLMs before adopting and
submitting their SIPs. 40 CFR 51.308(i). States must provide FLMs an
opportunity for consultation, in person and at least 60 days prior to
holding any public hearing on the SIP. This consultation must include
the opportunity for the FLMs to discuss their assessment of impairment
of visibility in any Class I area and to offer recommendations on the
development of the RPGs and on the development and implementation of
strategies to address visibility impairment. Further, a state must
include in its SIP a description of how it addressed any comments
provided by the FLMs. Finally, a SIP must provide procedures for
continuing consultation between the state and FLMs regarding the
state's visibility protection program, including development and review
of SIP revisions, five-year progress reports, and the implementation of
other programs having the potential to contribute to impairment of
visibility in Class I areas.
C. Our Proposal
We signed our notice of proposed rulemaking on May 23, 2013,\12\
and it was published in the Federal Register on June 10, 2013 (78 FR
34738). In our 2013 proposal, we proposed to approve many of Wyoming's
regional haze SIP, including the State's identification of its BART
sources, its identification of those BART sources that may be
anticipated to cause or contribute to visibility impairment, and the
State's BART determinations for PM. Because of deficiencies in
Wyoming's NOX BART analyses, however, we proposed to
disapprove the NOX BART emissions limitations for a number
of sources, as well as the reasonable progress goals and long-term
strategy. We proposed to address the NOX BART requirements
for these sources and the other deficiencies in the Wyoming plan in a
FIP, based on our analysis of the relevant factors. For several BART
sources we also asked in the proposed rulemaking if interested parties
had additional information regarding the BART factors and EPA's
proposed determinations, for example our weighing of average costs,
incremental costs, visibility improvement, and timing of installation
of such controls, and in light of such information, whether the
interested parties thought the Agency should consider another BART
control technology option that could be finalized either instead of, or
in conjunction with, BART as proposed.\13\
---------------------------------------------------------------------------
\12\ On May 15, 2012 the EPA signed the first proposed rule on
the Wyoming Regional Haze SIP which proposed to partially approve
and partially disapprove the Wyoming state plan. The EPA published
the proposed rule in the Federal Register for public comment on June
4, 2012. This public Federal Register notice may be found at 77 FR
33022 (June 4, 2012). EPA then obtained an extension to the Consent
Decree deadline in order to re-propose the Wyoming regional haze
plan based on data generated after the conclusion of the original
comment period. In this document, all references to ``proposal'' or
``proposal notice'' refer to the notice published on June 10, 2013
unless otherwise stated.
\13\ E.g., 78 FR 34777. The proposed notice also explained that
``[t]he Agency will take the comments and testimony received, as
well as any further SIP revisions submitted by the State, into
consideration in our final promulgation. Supplemental information
received may lead the Agency to adopt final SIP and/or FIP
regulations that reflect a different BART control technology option,
or impact other proposed regulatory provisions, which differ from
this proposal.'' 78 FR 34777.
---------------------------------------------------------------------------
In our 2013 proposal we proposed to disapprove the following:
[[Page 5038]]
The State's nitrogen oxides (NOX) best
available retrofit technology (BART) determinations for PacifiCorp Dave
Johnston Units 3 and 4, PacifiCorp Naughton Units 1 and 2, PacifiCorp
Wyodak Unit 1, and Basin Electric Laramie River Units 1, 2, and 3.
The State's NOX reasonable progress
determinations for PacifiCorp Dave Johnston Units 1 and 2.
Wyoming's reasonable progress goals (RPGs).
The State's monitoring, recordkeeping, and reporting
requirements in Chapter 6.4 of the SIP.
Portions of the State's long-term strategy (LTS) that rely
on or reflect other aspects of the regional haze SIP that we are
disapproving.
The provisions necessary to meet the requirements for the
coordination of the review of the reasonably attributable visibility
impairment (RAVI) and the regional haze LTS.
We proposed the promulgation of a FIP to address the deficiencies
in the Wyoming regional haze SIP that we identified in the proposed
notice. The proposed FIP included the following elements:
NOX BART determinations and limits for
PacifiCorp Dave Johnston Units 3 and 4, PacifiCorp Naughton Units 1 and
2, PacifiCorp Wyodak Unit 1, and Basin Electric Laramie River Units 1,
2, and 3.
NOX reasonable progress determinations and
limits for PacifiCorp Dave Johnston Units 1 and 2.
RPGs consistent with the SIP limits proposed for approval
and the proposed FIP limits.
Monitoring, recordkeeping, and reporting requirements
applicable to all BART and reasonable progress sources for which there
is a SIP or FIP emissions limit.
LTS elements pertaining to emission limits and compliance
schedules for the proposed BART and reasonable progress FIP emission
limits.
Provisions to ensure the coordination of the RAVI and
regional haze LTS.
We also requested comment on an alternative proposal, related to
the State's NOX BART determinations, for PacifiCorp Jim
Bridger Units 1 and 2, that would involve disapproval and the
promulgation of a FIP.
D. Public Participation
We requested comments on all aspects of our proposed action. In our
proposed rulemaking, we provided a 60-day comment period, with the
comment period closing on August 9, 2013. We also held a public hearing
on June 24, 2013, in Cheyenne, Wyoming. We received requests from
Wyoming's governor, congressional delegation, and Department of
Environmental Quality (DEQ), among others, for additional public
hearings and an extended public comment period. As a result, we held
two more public hearings. We held a hearing on July 17, 2013, in
Cheyenne, Wyoming, and on July 26, 2013, in Casper, Wyoming. We also
extended the comment period to August 26, 2013. We provided public
notice of the additional hearings and extension of the public comment
period on July 8, 2013. 78 FR 40654.
II. Final Action
Based upon comments received on our proposed action, in this final
action we are partially approving and partially disapproving Wyoming's
regional haze SIP submitted on January 12, 2011. We are approving the
majority of the State's regional haze determinations. For the fifteen
coal fired power plant units in Wyoming subject to the regional haze
requirements, we are approving the State's NOX emission
control technology decisions for 10 of those units. We are also
approving the State's plan for the non-power plant facilities subject
to regional haze requirements and the State's plan for control of PM.
We are approving all aspects of Wyoming's SIP, except for the following
elements which we are disapproving:
The State's NOX BART determinations for
PacifiCorp Dave Johnston Unit 3, PacifiCorp Wyodak Unit 1, and Basin
Electric Laramie River Units 1, 2, and 3.
Wyoming's RPGs.
The State's monitoring, recordkeeping, and reporting
requirements in Chapter 6.4 of the SIP.
Portions of the State's LTS that rely on or reflect other
aspects of the regional haze SIP that we are disapproving.
The provisions necessary to meet the requirements for the
coordination of the review of the RAVI and the regional haze LTS.
The final FIP includes the following elements:
NOX BART determinations and emission limits for
PacifiCorp Dave Johnston Unit 3, Wyodak Unit 1, and Basin Electric
Laramie River Units 1, 2, and 3.
RPGs consistent with the SIP emission limits finalized for
approval and the finalized FIP emission limits.
Monitoring, recordkeeping, and reporting requirements
applicable to all BART sources for which there is a SIP or FIP
emissions limit.
LTS elements pertaining to emission limits and compliance
schedules for the finalized FIP emission limits.
Provisions to ensure the coordination of the RAVI and
regional haze LTS.
Although we are promulgating a Federal plan, a state may always
submit a new regional haze SIP to EPA for review and we would welcome
such a submission. The CAA requires EPA to take action on such a SIP
submittal that is determined to be complete within 12 months. If the
State were to submit a revision meeting the requirements of the CAA and
the regional haze regulations, we would propose approval of the State's
plan as expeditiously as practicable. We are mindful of the costs of
our final action but have considered the costs and visibility
improvement that other states and EPA have required for BART controls.
Table 1 shows the NOX BART control technologies,
associated cost, and emission reductions for each source that is
subject to the FIP.
Table 1--Control Technologies, Costs, Emission Limits, and Cost Effectiveness for Sources Subject to the FIP
--------------------------------------------------------------------------------------------------------------------------------------------------------
Emission limit--lb/ Average cost-
Source Technology * MMBtu (30-day Total capital cost Total annualized effectiveness ($/
rolling average) ($) cost ($) ton)
--------------------------------------------------------------------------------------------------------------------------------------------------------
Dave Johnston Unit 3.............. New low-NOX burners (LNBs) 0.28 (for LNBs with $15,976,696 (for LNBs $1,828,137 (for LNBs $644 (for LNBs with
with overfire air (OFA) OFA). with OFA). with OFA). OFA).
and shut down in 2027; or
new LNBs with OFA and
selective catalytic
reduction (SCR) **.
[[Page 5039]]
Laramie River Unit 1.............. New LNBs/OFA and SCR...... 0.07................. $180,254,572......... $21,770,134......... $4,461.
Laramie River Unit 2.............. New LNBs with OFA and SCR. 0.07................. $188,826,333......... $22,691,467......... $4,424.
Laramie River Unit 3.............. New LNBs with OFA and SCR. 0.07................. $188,437,953......... $22,666,982......... $4,375.
Wyodak Unit 1..................... New LNBs with OFA and SCR. 0.07................. $119,501,862......... $12,714,153......... $4,036.
--------------------------------------------------------------------------------------------------------------------------------------------------------
\*\ The technology listed is the technology evaluated as BART, but sources can choose to use another technology or combination of technologies to meet
established limits.
\**\ As used in this and the following tables, ``new'' means replacing the control technology that was in place at the time of the State's BART analyses
in May 2009 with new control technology, most of which was installed post-2009.
III. Changes From Proposed Rule and Reasons for Changes
A. Changes to Proposed Costs and Visibility Improvements
As described in this section and elsewhere in today's final rule,
we have revised our cost of compliance analysis and visibility
improvement modeling from our June 10, 2013 proposed action for all of
the BART and reasonable progress electric generating units (EGUs).
EPA revised the cost analyses from those found in the proposed rule
based upon input from various commenters. Some of factors that caused
us to revise our cost estimates included accounting for site elevation
in the SCR capital cost, change in SCR reagent to anhydrous ammonia
from urea, change in auxiliary electrical cost from market price to
generating cost, change in urea SNCR chemical utilization for some
units due to high furnace temperatures, and consideration of shorter
plant lifetimes in some instances. In addition, EPA incorporated some
of the costs provided by commenters in their site specific cost
estimates where we found those costs to be sufficiently supported. Per
EPA's Control Cost Manual (CCM), use of site specific cost estimates is
preferable to the use of generalized costs where those site specific
costs can be supported and are appropriate.
EPA addressed comments on the visibility improvement modeling in
the proposed rule by developing a new protocol that makes several
improvements in the modeling, including the use of the current
regulatory version of the CALPUFF model (version 5.8), the use of an
improved method to assess the effects of pollutants on light scattering
and visibility impairment (Method 8), the use of lower background
ammonia concentrations, and the use of an ammonia limiting correction
for BART sources with multiple units. In particular, we have used new
values for ammonia background that reflect robust monitoring data and
the appropriate default concentrations for the geography in the state.
The results of our revised cost analysis, along with the revised
visibility impacts, are presented in Tables 2 through 17 below and
summarized for each source below the set of tables for that source.
Details regarding our revised cost analysis and visibility improvement
modeling can be found in the docket.14 15
---------------------------------------------------------------------------
\14\ Andover Technology Partners, ``Cost of NOX
Controls on Wyoming EGUs'', October 28, 2013; Wyoming EGU BART and
Reasonable Progress Costs--10/28/2013; Wyoming EGU BART and
Reasonable Progress Costs for Jim Bridger--10/28/2013.
\15\ Air Quality Modeling Protocol: Wyoming Regional Haze
Federal Implementation Plan, U.S. EPA, January, 2014.
Table 2--Summary of EPA's Laramie River Unit 1 NOX BART Analysis
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(Delta
Emission rate Incremental deciview for
(lb/MMBtu; Emission Annualized Average cost cost the maximum
Control technology annual reduction costs effectiveness effectiveness 98th
average) (tpy) ($/ton) ($/ton) percentile
impact at
Badlands
National Park)
--------------------------------------------------------------------------------------------------------------------------------------------------------
New LNBs with OFA....................................... 0.19 1,556 $2,268,806 $1,458 .............. 0.18
New LNBs with OFA and selective non-catalytic reduction 0.15 2,445 8,554,896 3,485 $6,993 0.28
(SNCR).................................................
New LNBs with OFA and SCR............................... 0.05 4,880 21,770,134 4,461 5,449 0.57
--------------------------------------------------------------------------------------------------------------------------------------------------------
[[Page 5040]]
Table 3--Summary of EPA's Laramie River Unit 2 NOX BART Analysis
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(Delta
Emission rate Incremental deciview for
(lb/MMBtu; Emission Annualized Average cost cost the maximum
Control technology annual reduction costs effectiveness effectiveness 98th
average) (tpy) ($/ton) ($/ton) percentile
impact at
Badlands
National Park)
--------------------------------------------------------------------------------------------------------------------------------------------------------
New LNBs with OFA....................................... 0.19 1823 $2,268,806 $1,244 .............. 0.18
New LNBs with OFA and SNCR.............................. 0.15 2,717 8,531,631 3,140 $7,006 0.27
New LNBs with OFA and SCR............................... 0.05 5,129 22,691,467 4,424 5,871 0.53
--------------------------------------------------------------------------------------------------------------------------------------------------------
Table 4--Summary of EPA's Laramie River Unit 3 NOX BART Analysis
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(Delta
Emission rate Incremental deciview for
(lb/MMBtu; Emission Annualized Average cost cost the maximum
Control technology annual reduction costs effectiveness effectiveness 98th
average) (tpy) ($/ton) ($/ton) percentile
impact at
Badlands
National Park)
--------------------------------------------------------------------------------------------------------------------------------------------------------
New LNBs with OFA....................................... 0.19 1789 $2,268,806 $1,268 .............. 0.18
New LNBs with OFA and SNCR.............................. 0.15 2,706 8,643,839 3,194 $6,951 0.27
New LNBs with OFA and SCR............................... 0.05 5,181 22,666,982 4,375 5,667 0.52
--------------------------------------------------------------------------------------------------------------------------------------------------------
EPA's January 2014 modeling protocol, Appendix H, shows the model
predicted visibility improvement for each emissions control technology
at each of the Class I areas that we modeled in our analysis. For
Laramie River we modeled visibility impairment at Badlands National
Park, Wind Cave National Park, Rawah Wilderness Area, and Rocky
Mountain National Park. At Laramie River Unit 1 the model visibility
improvements with LNB/OFA/SCR were 0.57 deciviews at Badlands National
Park, 0.47 deciviews at Wind Cave National Park, 0.25 deciviews at
Rawah Wilderness Area, and 0.39 at Rocky Mountain National Park. At
Laramie River Unit 2 the model visibility improvements with LNB/OFA/SCR
were 0.53 deciviews at Badlands, 0.43 deciviews at Wind Cave, 0.26
deciviews at Rawah, and 0.31 at Rocky Mountain. At Laramie River Unit 3
the model visibility improvements with LNB/OFA/SCR were 0.52 deciviews
at Badlands, 0.44 deciviews at Wind Cave, 0.23 deciviews at Rawah, and
0.28 at Rocky Mountain.
Table 5--Summary of EPA's Jim Bridger Unit 1 NOX BART Analysis
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(Delta
deciview for
Emission rate Emission Average cost Incremental the maximum
Control technology (lb/MMBtu; reduction Annualized effectiveness cost 98th
annual (tpy) costs ($/ton) effectiveness percentile
average) ($/ton) impact at
Bridger
Wilderness
Area) **
--------------------------------------------------------------------------------------------------------------------------------------------------------
New LNBs with SOFA...................................... 0.18 4,558 $1,167,297 $256 .............. 0.17/0.23
New LNBs with SOFA and SNCR............................. 0.14 5,332 4,330,052 812 $4,088 0.20/0.27
New LNBs with SOFA and SCR.............................. 0.05 7,352 19,372,105 2,635 7,447 0.27/0.37
--------------------------------------------------------------------------------------------------------------------------------------------------------
* Values shown are model results using ammonia based on monitoring and default data; values in straight font are model results using a monitored monthly
varying concentration/values in italics are model results using an IWAQM default 0.5 ppb background ammonia.
Table 6--Summary of EPA's Jim Bridger Unit 2 NOX BART Analysis
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(Delta
deciview for
Emission rate Emission Average cost Incremental the maximum
Control technology (lb/MMBtu; reduction Annualized effectiveness cost 98th
annual (tpy) costs ($/ton) effectiveness percentile
average) ($/ton) impact at
Bridger
Wilderness
Area) *
--------------------------------------------------------------------------------------------------------------------------------------------------------
New LNBs with SOFA...................................... 0.19 3,787 $1,167,297 $308 .............. 0.16/0.21
New LNBs with SOFA and SNCR............................. 0.15 4,545 4,291,184 944 $4,122 0.19/0.25
New LNBs with SOFA and SCR.............................. 0.05 6,554 22,307,492 3,403 8,968 0.27/0.36
--------------------------------------------------------------------------------------------------------------------------------------------------------
* Values shown are model results using ammonia based on monitoring and default data; values in straight font are model results using a monitored monthly
varying concentration/values in italics are model results using an IWAQM default 0.5 ppb background ammonia.
[[Page 5041]]
Table 7--Summary of EPA's Jim Bridger Unit 3 NOX BART Analysis
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(Delta
deciview for
Emission rate Emission Average cost Incremental the maximum
Control technology (lb/MMBtu; reduction Annualized effectiveness cost 98th
annual (tpy) costs ($/ton) effectiveness percentile
average) ($/ton) impact at
Bridger
Wilderness
Area) *
--------------------------------------------------------------------------------------------------------------------------------------------------------
New LNBs with SOFA...................................... 0.20 3,710 $1,167,297 $315 .............. 0.14/0.19
New LNBs with SOFA and SNCR............................. 0.16 4,539 4,458,776 982 $3,972 0.17/0.23
New LNBs with SOFA and SCR.............................. 0.05 6,799 22,573,920 3,320 8,015 0.26/0.35
--------------------------------------------------------------------------------------------------------------------------------------------------------
* Values shown are model results using ammonia based on monitoring and default data; values in straight font are model results using a monitored monthly
varying concentration/values in italics are model results using an IWAQM default 0.5 ppb background ammonia.
Table 8--Summary of EPA's Jim Bridger Unit 4 NOX BART Analysis
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(Delta
deciview for
Emission rate Emission Average cost Incremental the maximum
Control technology (lb/MMBtu; reduction Annualized effectiveness cost 98th
annual (tpy) costs ($/ton) effectiveness percentile
average) ($/ton) impact at
Rawah
Wilderness
Area) *
--------------------------------------------------------------------------------------------------------------------------------------------------------
New LNBs with SOFA...................................... 0.19 4,161 $1,167,297 $281 .............. 0.25/0.23
New LNBs with SOFA and SNCR............................. 0.15 4,956 4,372,457 882 $4,035 0.30/0.28
New LNBs with SOFA and SCR.............................. 0.05 7,108 19,494,417 2,743 7,027 0.45/0.42
--------------------------------------------------------------------------------------------------------------------------------------------------------
* Values shown are model results using ammonia based on monitoring and default data; values in straight font are model results using a monitored monthly
varying concentration/values in italics are model results using an IWAQM default 0.5 ppb background ammonia.
EPA's January 2014 modeling protocol, Appendix H, shows the model
predicted visibility improvement for each emissions control technology
at each of the Class I areas that we modeled in our analysis of Jim
Bridger. Model simulations were performed using a monthly varying
background ammonia concentration and using the IWAQM default
concentration for forested areas of 0.5 ppb. For Jim Bridger we modeled
visibility impairment at Bridger Wilderness Area, Fitzpatrick
Wilderness Area, Mt Zirkel Wilderness Area, Rawah Wilderness Area,
Rocky Mountain National Park, Grand Teton National Park, Teton
Wilderness Area, Washakie Wilderness Area and Yellowstone National
Park. Under the State's LTS, LNB/OFA/SCR would be required on Jim
Bridger Units 1 and 2 in 2022 and 2021. Under the State's LTS, LNB/OFA/
SCR would be required on Jim Bridger Units 3 and 4 in 2015 and 2016.
For Jim Bridger Unit 1, using monthly varying ammonia
concentrations, model visibility improvements with LNB/OFA/SCR were:
0.37 deciviews at Bridger; 0.26 deciviews at Fitzpatrick; 0.29
deciviews at Mt Zirkel; 0.35deciviews at Rawah; 0.36 deciviews at Rocky
Mountain; 0.17 deciviews at Grand Teton; 0.14 deciviews at Teton; 0.19
deciviews at Washakie; and 0.15 deciviews at Yellowstone.
For Jim Bridger Unit 1, using a constant 0.5 ppb ammonia
concentration, model visibility improvements with LNB/OFA/SCR were:
0.37 deciviews at Bridger; 0.26 deciviews at Fitzpatrick; 0.29
deciviews at Mt Zirkel; 0.35 deciviews at Rawah; 0.36 deciviews at
Rocky Mountain; 0.17 deciviews at Grand Teton; 0.14 deciviews at Teton;
0.19 deciviews at Washakie; and 0.15 deciviews at Yellowstone.
For Jim Bridger Unit 2, using monthly varying ammonia
concentrations, model visibility improvements with LNB/OFA/SCR were:
0.36 deciviews at Bridger; 0.26 deciviews at Fitzpatrick; 0.28
deciviews at Mt Zirkel; 0.35 deciviews at Rawah; 0.36 deciviews at
Rocky Mountain; 0.16 deciviews at Grand Teton; 0.14 deciviews at Teton;
0.19 deciviews at Washakie; and 0.14 deciviews at Yellowstone.
For Jim Bridger Unit 2, using a constant 0.5 ppb ammonia
concentration, model visibility improvements with LNB/OFA/SCR were:
0.36 deciviews at Bridger; 0.26 deciviews at Fitzpatrick; 0.28
deciviews at Mt Zirkel; 0.35 deciviews at Rawah; 0.36 deciviews at
Rocky Mountain; 0.16 deciviews at Grand Teton; 0.14 deciviews at Teton;
0.19 deciviews at Washakie; and 0.14 deciviews at Yellowstone.
For Jim Bridger Unit 3, using monthly varying ammonia
concentrations, model visibility improvements with LNB/OFA/SCR were:
0.35 deciviews at Bridger; 0.25 deciviews at Fitzpatrick; 0.28
deciviews at Mt Zirkel; 0.33 deciviews at Rawah; 0.34 deciviews at
Rocky Mountain; 0.16 deciviews at Grand Teton; 0.14 deciviews at Teton;
0.18 deciviews at Washakie; and 0.14 deciviews at Yellowstone.
For Jim Bridger Unit 3, using a constant 0.5 ppb ammonia
concentration, model visibility improvements with LNB/OFA/SCR were:
0.35 deciviews at Bridger; 0.25 deciviews at Fitzpatrick; 0.28
deciviews at Mt Zirkel; 0.33 deciviews at Rawah; 0.34 deciviews at
Rocky Mountain; 0.16 deciviews at Grand Teton; 0.14 deciviews at Teton;
0.18 deciviews at Washakie; and 0.14 deciviews at Yellowstone.
For Jim Bridger Unit 4, using monthly varying ammonia
concentrations, model visibility improvements with LNB/OFA/SCR were:
0.38 deciviews at Bridger; 0.28 deciviews at Fitzpatrick; 0.19
deciviews at Mt Zirkel; 0.42 deciviews at Rawah; 0.38 deciviews at
Rocky Mountain; 0.32 deciviews at Grand Teton; 0.15 deciviews at Teton;
0.30 deciviews at Washakie; and 0.16 deciviews at Yellowstone.
For Jim Bridger Unit 4, using a constant 0.5 ppb ammonia
concentration, model visibility improvements with LNB/OFA/SCR were:
0.38 deciviews at Bridger; 0.28
[[Page 5042]]
deciviews at Fitzpatrick; 0.27 deciviews at Mt Zirkel; 0.42 deciviews
at Rawah; 0.38 deciviews at Rocky Mountain; 0.32 deciviews at Grand
Teton; 0.15 deciviews at Teton; 0.30 deciviews at Washakie; and 0.16
deciviews at Yellowstone.
Table 9--Summary of EPA's Dave Johnston Unit 3 NOX BART Analysis
[9 Year remaining useful life]
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(Delta
Emission rate Incremental deciview for
(lb/MMBtu; Emission Annualized Average cost cost the maximum
Control technology annual reduction costs effectiveness effectiveness 98th
average) (tpy) ($/ton) ($/ton) percentile
impact at Wind
Cave National
Park)
--------------------------------------------------------------------------------------------------------------------------------------------------------
New LNBs with OFA....................................... 0.22 2,837 $1,828,137 $644 .............. 0.33
New LNBs with OFA and SNCR.............................. 0.16 3,356 3,898,930 1,162 $3,988 0.39
New LNBs with OFA and SCR............................... 0.05 4,433 16,591,006 3,742 11,781 0.51
--------------------------------------------------------------------------------------------------------------------------------------------------------
Table 10--Summary of EPA's Dave Johnston Unit 3 NOX BART Analysis
[20 Year remaining useful life]
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(Delta
Emission rate Incremental deciview for
(lb/MMBtu; Emission Annualized Average cost cost the maximum
Control technology annual reduction costs effectiveness effectiveness 98th
average) (tpy) ($/ton) ($/ton) percentile
impact at Wind
Cave National
Park)
--------------------------------------------------------------------------------------------------------------------------------------------------------
New LNBs with OFA....................................... 0.22 2,837 $1,699,807 $599 .............. 0.33
New LNBs with OFA and SNCR.............................. 0.16 3,356 3,510,589 1,046 $3,488 0.39
New LNBs with OFA and SCR............................... 0.05 4,433 11,680,144 2,635 7,583 0.51
--------------------------------------------------------------------------------------------------------------------------------------------------------
Table 11--Summary of EPA's Dave Johnston Unit 4 NOX BART Analysis
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(Delta
Emission rate Incremental deciview for
(lb/MMBtu; Emission Annualized Average cost cost the maximum
Control technology annual reduction costs effectiveness effectiveness 98th
average) (tpy) ($/ton) ($/ton) percentile
impact at Wind
Cave National
Park)
--------------------------------------------------------------------------------------------------------------------------------------------------------
New LNBs with OFA....................................... 0.14 3,114 $767,342 $246 .............. 0.41
New LNBs with OFA and SNCR.............................. 0.11 3,505 2,541,600 725 $4,535 0.46
New LNBs with OFA and SCR............................... 0.05 4,377 14,158,899 3,235 13,312 0.57
--------------------------------------------------------------------------------------------------------------------------------------------------------
EPA's January 2014 modeling protocol, Appendix H, shows the model
predicted visibility improvement for each emissions control technology
at each of the Class I areas that we modeled in our analysis of Dave
Johnston. For Dave Johnston we modeled visibility impairment at
Badlands National Park, Wind Cave National Park, Mt Zirkel Wilderness
Area, Rawah Wilderness Area, and Rocky Mountain National Park. At Dave
Johnston Unit 3 the model visibility improvements with LNB/OFA/SCR were
0.47 deciviews at Badlands National Park, 0.51 deciviews at Wind Cave
National Park, 0.20 deciviews at Mt Zirkel Wilderness Area, 0.40
deciviews at Rawah Wilderness Area, and 0.28 at Rocky Mountain National
Park. At Dave Johnston Unit 4 the model visibility improvements with
LNB/OFA were 0.55 deciviews at Badlands National Park, 0.57 deciviews
at Wind Cave National Park, 0.24 deciviews at Mt Zirkel Wilderness
Area, 0.34 deciviews at Rawah Wilderness Area, and 0.33 deciviews at
Rocky Mountain National Park.
[[Page 5043]]
Table 12--Summary of EPA's Naughton Unit 1 NOX BART Analysis
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(Delta
deciview for
Emission rate Emission Average cost Incremental the Maximum
Control technology (lb/MMBtu; reduction Annualized effectiveness cost 98th
annual (tpy) costs ($/ton) effectiveness percentile
average) ($/ton) impact at
Bridger
Wilderness
Area) *
--------------------------------------------------------------------------------------------------------------------------------------------------------
New LNBs with OFA....................................... 0.21 2,100 $932,466 $444 .............. 0.22/0.26
New LNBs with OFA and SNCR.............................. 0.16 2,463 2,234,827 907 $3,584 0.26/0.30
New LNBs with OFA and SCR............................... 0.05 3,209 9,974,616 3,109 10,384 0.33/0.39
--------------------------------------------------------------------------------------------------------------------------------------------------------
* Values shown are model results using ammonia based on monitoring and default data; values in straight font are model results using a monitored monthly
varying concentration/values in italics are model results using an IWAQM default 0.5 ppb background ammonia.
Table 13--Summary of EPA's Naughton Unit 2 NOX BART Analysis
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(Delta
deciview for
Emission rate Emission Average cost Incremental the Maximum
Control technology (lb/MMBtu; reduction Annualized effectiveness cost 98th
annual (tpy) costs ($/ton) effectiveness percentile
average) ($/ton) impact at
Bridger
Wilderness
Area) *
--------------------------------------------------------------------------------------------------------------------------------------------------------
New LNBs with OFA....................................... 0.21 2,586 $883,900 $342 .............. 0.28/0.32
New LNBs with OFA and SNCR.............................. 0.16 3,024 2,480,832 820 $3,647 0.34/0.38
New LNBs with OFA and SCR............................... 0.05 3,922 10,062,750 2,566 8,440 0.42/0.46
--------------------------------------------------------------------------------------------------------------------------------------------------------
* Values shown are model results using ammonia based on monitoring and default data; values in straight font are model results using a monitored monthly
varying concentration/values in italics are model results using an IWAQM default 0.5 ppb background ammonia.
Table 14--Summary of EPA's Naughton Unit 3 NOX BART Analysis
[In lieu of conversion of Naughton Unit 3 to natural gas per PacifiCorp request]
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(Delta
deciview for
Emission rate Emission Average cost Incremental the Maximum
Control technology (lb/MMBtu; reduction Annualized effectiveness cost 98th
annual (tpy) costs ($/ton) effectiveness percentile
average) ($/ton) impact at
Bridger
Wilderness
Area) *
--------------------------------------------------------------------------------------------------------------------------------------------------------
Existing LNBs with OFA**................................ 0.33 442 $106,393 $240 .............. 0.05/0.07
Existing LNBs with OFA and SNCR......................... 0.23 1,673 3,852,377 2,303 $3,045 0.20/0.29
Existing LNBs with OFA and SCR.......................... 0.05 3,922 13,604,702 3,469 4,335 0.49/0.60
--------------------------------------------------------------------------------------------------------------------------------------------------------
* Values shown are model results using ammonia based on monitoring and default data; values in straight font are model results using a monitored monthly
varying concentration/values in italics are model results using an IWAQM default 0.5 ppb background ammonia.
** As used in this table, ``existing'' means the control technology that was in place at the time of the State's BART analyses in May 2009.
EPA's January 2014 modeling protocol, Appendix H, shows the model
predicted visibility improvement for each emissions control technology
at each of the Class I areas that we modeled in our analysis of
Naughton. For Naughton we modeled visibility impairment at Bridger
Wilderness Area, Fitzpatrick Wilderness Area, North Absaroka Wilderness
Area, Washakie Wilderness Area, Teton Wilderness Area, Grand Teton
National Park and Yellowstone National Park. Model simulations were
performed using a monthly varying background ammonia concentration and
using the IWAQM default concentration for forested areas of 0.5 ppb.
For Naughton Unit 1 model visibility improvements, using monthly
varying ammonia concentrations, with LNB/OFA and LNB/OFA/SCR were,
respectively: 0.22 and 0.33 deciviews at Bridger; 0.19 and 0.29
deciviews at Fitzpatrick; 0.10 and 0.14 at North Absaroka; 0.10 and
0.15 deciviews at Washakie; 0.10 and 0.16 deciviews at Teton; 0.15 and
0.23 deciviews at Grand Teton; and 0.12 and 0.18 deciviews at
Yellowstone.
For Naughton Unit 1 model visibility improvements, using a constant
0.5 ppb ammonia concentration, with LNB/OFA and LNB/OFA/SCR were,
respectively: 0.26 and 0.39 deciviews at Bridger; 0.22 and 0.30
deciviews at Fitzpatrick; 0.10 and 0.14 at North Absaroka; 0.12 and
0.17 deciviews at Washakie; 0.13 and 0.19 deciviews at Teton; 0.19 and
0.29 deciviews at Grand Teton; and 0.13 and 0.19 deciviews at
Yellowstone.
[[Page 5044]]
For Naughton Unit 2 model visibility improvements, using monthly
varying ammonia concentrations, with LNB/OFA and LNB/OFA/SCR were,
respectively: 0.28 and 0.42 deciviews at Bridger; 0.25 and 0.36
deciviews at Fitzpatrick; 0.12 and 0.17 at North Absaroka; 0.15 and
0.22 deciviews at Washakie; 0.14 and 0.21 deciviews at Teton; 0.18 and
0.28 deciviews at Grand Teton; and 0.16 and 0.22 deciviews at
Yellowstone.
For Naughton Unit 2 model visibility improvements, using a constant
0.5 ppb ammonia concentration, with LNB/OFA and LNB/OFA/SCR were,
respectively: 0.32 and 0.46 deciviews at Bridger; 0.26 and 0.38
deciviews at Fitzpatrick; 0.12 and 0.17 at North Absaroka; 0.16 and
0.22 deciviews at Washakie; 0.17 and 0.25 deciviews at Teton; 0.25 and
0.38 deciviews at Grand Teton; and 0.17 and 0.24 deciviews at
Yellowstone.
For Naughton Unit 3 model visibility improvements, using monthly
varying ammonia concentrations, with LNB/OFA and LNB/OFA/SCR were,
respectively: 0.05 and 0.49 deciviews at Bridger; 0.05 and 0.42
deciviews at Fitzpatrick; 0.03 and 0.24 at North Absaroka; 0.05 and
0.37 deciviews at Washakie; 0.04 and 0.38 deciviews at Teton; 0.04 and
0.38 deciviews at Grand Teton; and 0.04 and 0.39 deciviews at
Yellowstone.
For Naughton Unit 3 model visibility improvements, using a constant
0.5 ppb ammonia concentration, with LNB/OFA and LNB/OFA/SCR were,
respectively: 0.07 and 0.60 deciviews at Bridger; 0.05 and 0.44
deciviews at Fitzpatrick; 0.03 and 0.24 at North Absaroka; 0. and 0.
deciviews at Washakie; 0.05 and 0.39 deciviews at Teton; 0.06 and 0.41
deciviews at Grand Teton; and 0.05 and 0.40 deciviews at Yellowstone.
Table 15--Summary of EPA's Wyodak NOX BART Analysis
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(delta
Emission rate Incremental deciview for
(lb/MMBtu; Emission Annualized Average cost cost the maximum
Control technology annual reduction costs effectiveness effectiveness 98th
average) (tpy) ($/ton) ($/ton) percentile
impact at Wind
Cave National
Park)
--------------------------------------------------------------------------------------------------------------------------------------------------------
New LNBs with OFA....................................... 0.19 1,239 $1,272,427 $1,027 .............. 0.21
New LNBs with OFA and SNCR.............................. 0.15 1,914 3,726,573 1,947 3,635 0.32
New LNBs with OFA and SCR............................... 0.05 3,735 15,073,502 4,036 6,233 0.61
--------------------------------------------------------------------------------------------------------------------------------------------------------
EPA's January 2014 modeling protocol, Appendix H, shows the model
predicted visibility improvement for each emissions control technology
at each of the Class I areas that we modeled in our analysis of Wyodak
. For Wyodak we modeled visibility impairment at Badlands National Park
and Wind Cave National Park. At Wyodak Unit 1 the model visibility
improvements with LNB/OFA/SCR were 0.61 deciviews at Wind Cave and 0.38
deciviews at Badlands National Park.
Table 16--Summary of EPA's Dave Johnston Unit 1 NOX Reasonable Progress Analysis
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(delta
Emission rate Incremental deciview for
(lb/MMBtu; Emission Annualized Average cost cost the maximum
Control technology annual reduction costs effectiveness effectiveness 98th
average) (tpy) ($/ton) ($/ton) percentile
impact at Wind
Cave National
Park)
--------------------------------------------------------------------------------------------------------------------------------------------------------
LNBs with OFA *......................................... 0.20 1,226 $1,214,000 $990 .............. 0.12
LNBs with OFA and SNCR.................................. 0.15 1,466 2,096,430 1,430 3,670 0.14
LNBs with OFA and SCR................................... 0.05 1,947 6,808,374 3,496 9,798 0.18
--------------------------------------------------------------------------------------------------------------------------------------------------------
* As used in this and the following tables, control technology that is not preceded by either ``new'' or ``existing'' (as in the above tables) means the
control technology will be installed for the first time.
Table 17--Summary of EPA's Dave Johnston Unit 2 NOX Reasonable Progress Analysis
--------------------------------------------------------------------------------------------------------------------------------------------------------
Visibility
improvement
(delta
Emission rate Incremental deciview for
(lb/MMBtu; Emission Annualized Average cost cost the maximum
Control technology annual reduction costs effectiveness effectiveness 98th
average) (tpy) ($/ton) ($/ton) percentile
impact at Wind
Cave National
Park)
--------------------------------------------------------------------------------------------------------------------------------------------------------
LNBs with OFA........................................... 0.20 1,180 $1,441,146 $1,221 .............. 0.11
LNBs with OFA and SNCR.................................. 0.15 1,425 2,335,022 1,638 3,645 0.14
LNBs with OFA and SCR................................... 0.05 1,916 7,037,969 3,673 9,588 0.18
--------------------------------------------------------------------------------------------------------------------------------------------------------
[[Page 5045]]
B. Changes to Our Proposed Determinations
1. Dave Johnston Unit 3
We proposed to require PacifiCorp Dave Johnston Unit 3 to meet a
FIP emission limit of 0.07 lb/MMBtu (30-day rolling average) for
NOX BART (assumes the installation of LNBs/OFA plus SCR).
Based on our revised costs of compliance and visibility impacts, we
would still conclude that NOX BART is an emission limit of
0.07 lb/MMBtu (30-day rolling average). PacifiCorp submitted comments
on our proposed rulemaking on August 26, 2013. In those comments,
PacifiCorp indicated in various places (e.g., page 37) that instead of
installing SCR, it would shut down Dave Johnston Unit 3 in 2027. Our
regulatory language now provides PacifiCorp two alternative paths to
compliance with the FIP. The first path includes a requirement for Dave
Johnston Unit 3 to cease operation by December 31, 2027. For this path,
we are requiring Dave Johnston Unit 3 to meet a FIP limit of 0.28 lb/
MMBtu (30-day rolling average) no later than five years after the date
of our final action. This emission limit assumes the installation of
LNBs/OFA. The second compliance path gives PacifiCorp the option to
instead meet a 0.07 lb/MMBtu emission limit (assumes installation of
SCR) within five years of our final action with no requirement for shut
down.
EPA met with PacifiCorp on October 31, 2013, to clarify the
comments submitted by PacifiCorp (see October 31, 2013 memo to docket).
Specifically, EPA asked if, in lieu of a requirement for SCR,
PacifiCorp was asking for EPA to include an enforceable requirement in
the FIP for Dave Johnston Unit 3 to shut down in 2027, and for EPA to
make a BART determination based on that limited remaining useful life.
PacifiCorp confirmed that it did want EPA to include an enforceable
requirement in the FIP for PacifiCorp to shut down Dave Johnston Unit 3
by December 31, 2027, and to make a BART determination accordingly. As
detailed in the following section, we determined that if the unit shuts
down by December 31, 2027, SCR would no longer be NOX BART.
Generally, EPA does not interpret the regional haze rule to provide
us with authority to make a BART determination that requires the
shutdown of a source. In other states, we have approved state-adopted
requirements for the shutdown of a source, which have usually been
negotiated between the source operator and the state, and we have
accordingly approved BART determinations that took into account the
resulting shorter useful life of the affected source. In the case of
Dave Johnson Unit 3, the State has not submitted a SIP revision to
require the shutdown that PacifiCorp intends to implement, so there is
no enforceable shutdown commitment that we can approve. We believe that
without an enforceable requirement for the shutdown, we cannot make a
BART determination that reflects the shorter planned useful life of the
unit. Therefore, we are incorporating the shutdown requirement into one
of the two compliance paths available to PacifiCorp, in order to allow
it to only be required to install and maintain the less expensive LNBs/
OFA emission controls rather than the more expensive SCR controls. We
welcome a SIP revision that would make the shutdown requirement State
law, and we would withdraw the shutdown requirement from the SIP upon
approving such a SIP revision.
2. Dave Johnston Unit 4
We proposed to require PacifiCorp Dave Johnston Unit 4 to meet a
FIP emission limit of 0.12 lb/MMBtu (30-day rolling average) for
NOX BART (assuming the installation of LNBs/OFA with SNCR).
Based on our revised costs of compliance and visibility impacts, we no
longer conclude that NOX BART is an emission limit of 0.12
lb/MMBtu (30-day rolling average). Based on our new cost and visibility
improvement numbers, we conclude that NOX BART is
represented by the SIP emission limit of 0.15 lb/MMBtu (30-day rolling
average) for this unit. This emission limit assumes the installation of
LNBs/OFA. As such, we are approving Wyoming's NOX BART
determination for Dave Johnston Unit 4.
3. Naughton Units 1 and 2
We proposed to require PacifiCorp Naughton Units 1 and 2 to meet a
FIP emission limit of 0.07 lb/MMBtu (30-day rolling average) for
NOX BART (assuming the installation of LNBs/OFA with SCR).
As detailed in the next section, based on our revised costs of
compliance and visibility impacts, we no longer conclude that
NOX BART is an emission limit of 0.07 lb/MMBtu (30-day
rolling average). Based on our new cost and visibility improvement
numbers, we conclude that NOX BART is represented by the SIP
emission limit of 0.26 lb/MMBtu (30-day rolling average) for each unit.
This emission limit assumes the installation of LNBs/OFA. As such, we
are approving Wyoming's NOX BART determination for Naughton
Units 1 and 2.
4. Naughton Unit 3
We proposed to approve the State's NOX BART
determination for Naughton Unit 3, which was an emission limit of 0.07
lb/MMBtu (30-day rolling average) (assumes the installation of LNBs/OFA
with SCR). PacifiCorp submitted comments on our proposed rulemaking on
August 26, 2013. In those comments, PacifiCorp indicated (page 72) that
instead of installing SCR as required by the SIP, it plans to convert
Naughton Unit 3 to natural gas in 2018 without installation of any
post-combustion control of NOX emissions. Conversion to
natural gas in this manner can be expected to result in NOX
emissions that are higher than the 0.07 lb/MMBtu limit in the SIP
combined with much lower SO2 and PM emissions, with a
substantially lower overall remaining impact on visibility. On July 5,
2013, Wyoming issued Air Quality permit MD-14506 to PacifiCorp that
reflects the conversion of Naughton Unit 3 to natural gas in June of
2018. EPA met with PacifiCorp on October 31, 2013, to clarify the
comments submitted by PacifiCorp (see October 31, 2013 memo to docket).
PacifiCorp requested that EPA include in its final action the emission
limits for SO2, PM, and NOX that the State had in
its permit MD-14506 that it issued to PacifiCorp. EPA supports
PacifiCorp's conversion of Naughton Unit 3 to natural gas. However, we
have the authority and obligation to take action on the SIP as
submitted by the State, and there is no basis to disapprove the SIP.
Since we are approving the SIP, we do not have authority to impose FIP
limits even if independently requested by a source. Therefore, we
cannot use the FIP to relieve Naughton Unit 3 of the obligation to
achieve the 0.07 lb/MMBtu NOX emission limit in the SIP nor
to impose emission limits for SO2 and PM that reflect the
planned conversion to natural gas. Under the terms of the SIP, the
compliance deadlines for the emission limits in the SIP for Naughton
Unit 3 do not become effective until five years after our final action.
We understand that Wyoming intends to submit a revision to their
regional haze SIP for Naughton Unit 3 that reflects the BART
NOX emission limits in its permit MD-14506 as soon as
practicable. EPA intends to act on this SIP revision in an expedited
timeframe to reflect the conversion of Naughton Unit 3 to natural gas
and a revised BART NOX limit. In our final action we are
approving Wyoming's NOX BART determination for Naughton Unit
3. Our regulatory language reflects the following emission limit for
Naughton
[[Page 5046]]
Unit 3 for NOX: 0.07 lb/MMBtu (30-day rolling average).
5. Wyodak
We proposed to require PacifiCorp Wyodak Unit 1 to meet a FIP
emission limit of 0.17 lb/MMBtu (30-day rolling average) for
NOX BART (assuming the installation of LNBs/OFA with SNCR).
Based on our revised costs of compliance and visibility impacts, as
well as comments received during the public comment period (see section
V), we no longer conclude that NOX BART is an emission limit
of 0.17 lb/MMBtu (30-day rolling average). Based on our new cost and
visibility improvement numbers, we conclude that NOX BART is
a FIP emission limit of 0.07 lb/MMBtu (30-day rolling average) for this
unit. This emission limit assumes the installation of LNBs/OFA with
SCR. As detailed in the next section, based on our weighing of the five
factors, we find that the average cost-effectiveness of SCR ($4,036/
ton) and the incremental cost-effectiveness ($6,233/ton), combined with
a visibility improvement of 0.61 deciviews at the most impacted Class I
area, makes the selection of SCR for BART reasonable.
6. Jim Bridger
In our proposal, we proposed to approve the State's NOX
BART and LTS determinations for Jim Bridger Units 1 and 2. The State's
BART determination required each unit to meet an emissions limit of
0.26 lb/MMBtu (30-day rolling average) within five years of our
approval of the SIP, based on new LNB plus OFA. The LTS determination
required each unit to meet an emission limit of 0.07 lb/MMBtu (30-day
rolling average) by December 31, 2022, and December 31, 2021,
respectively. EPA proposed to approve these compliance dates for
numerous reasons as discussed in detail in our proposed rulemaking. 78
FR 34755. We also proposed an alternative FIP BART determination that
would require Jim Bridger Units 1 and 2 to meet an emission limit of
0.07 lb/MMBtu (30-day rolling average) within five years of our final
rulemaking. 78 FR 34780. We are finalizing our proposed approval of the
State's BART and LTS determinations for Jim Bridger Units 1 and 2,
although the reasons for our final action on Jim Bridger Units 1 and 2
have changed from our proposed action.
In our proposed rulemaking, we stated:
EPA is proposing to determine that BART for all units at Jim
Bridger would be SCR if the units were considered individually,
based on the five factors, without regard for the controls being
required at other units in the PacifiCorp system. However, when the
cost of BART controls at other PacifiCorp owned EGUs is considered
as part of the cost factor for the Jim Bridger Units, EPA is
proposing that Wyoming's determination that NOX BART for
these units is new LNB plus OFA for is reasonable. Considering costs
broadly, it would be unreasonable to require any further retrofits
at this source within five years of our final action. We note that
the CAA establishes five years at the longest period that can be
allowed for compliance with BART emission limits.'' 78 FR 34756.
However, as discussed in detail in section V.D.2 below, we do not
think PacifiCorp has presented ample evidence to show that it would
be unreasonable or not feasible for them to install numerous SCRs
within the five year BART period. Nonetheless, we are approving the
State's BART determination and LTS for Jim Bridger Units 1 and 2
based on our consideration of the five factors, as detailed in the
next section.
We are approving the State's SIP requirement that Jim Bridger Units
1 and 2 meet an emission limit of 0.07 lb/MMBtu (30-day rolling
average) by 2022 and 2021, respectively. We are also approving the
State's BART determination that requires Jim Bridger Units 1 and 2 to
meet a NOX emission limit of 0.26 lb/MMBtu (30-day rolling
average) within five years of our final action.
For Jim Bridger Units 3 and 4 we proposed to approve the SIP with
regard to the State's determination that the appropriate level of
NOX control for Units 3 and 4 for purposes of reasonable
progress is the SCR-based emission limit in the SIP of 0.07 lb/MMBtu,
with compliance dates of December 31, 2015 for Unit 3 and December 31,
2016 for Unit 4. In our proposal we noted that since the State is
requiring PacifiCorp to install the LTS controls within the timeline
that BART controls would have to be installed pursuant to 40 CFR
51.308(e)(iv), we proposed to approve the State's compliance schedule
and emission limit of 0.07 lb/MMBtu for Jim Bridger Units 3 and 4 as
meeting the BART requirements.
We are finalizing our proposed approval of the State's BART and LTS
determinations for Jim Bridger Units 3 and 4, although, similar to
Units 1 and 2, the reasons for our final action on Units 3 and 4 have
changed from our proposed action.
7. Dave Johnston Units 1 and 2
We proposed to require PacifiCorp Dave Johnston Units 1 and 2 to
meet a FIP emission limit of 0.22 lb/MMBtu (30-day rolling average) for
NOX under reasonable progress (assuming the installation of
LNBs/OFA). As detailed in the next section, based on our revised costs
and visibility impacts, we no longer conclude that an emission limit of
0.22 lb/MMBtu (30-day rolling average) is warranted. We are approving
Wyoming's NOX reasonable progress determinations for Dave
Johnston Units 1 and 2 (i.e., no controls).
IV. Basis for Our Final Action
We have fully considered all significant comments on our proposal
and have concluded that no changes from our proposal other than those
discussed in detail above are warranted. Our action is based on an
evaluation of Wyoming's regional haze SIP against the regional haze
requirements at 40 CFR 51.300-51.309 and CAA sections 169A and 169B.
All general SIP requirements contained in CAA section 110, other
provisions of the CAA, and our regulations applicable to this action
were also evaluated. The purpose of this action is to ensure compliance
with these requirements. Our authority for action on Wyoming's SIP
submittal is based on CAA section 110(k). Our authority to promulgate a
FIP is based on CAA section 110(c).
In our proposal, EPA asked interested parties to provide additional
information on both our evaluation of the BART factors and our proposed
determinations. 78 FR 38745. We provided notice that any supplemental
information we received could lead us to select BART control
technologies or compliance deadlines that differed from our proposal.
In response to this request, we received extensive comments on the
visibility modeling and cost estimates that we provided in the proposal
for NOX BART control technologies. As a result of these
comments, we have revised our visibility modeling and cost estimates.
The details of these changes and our reasons for making them are
provided elsewhere in this document and in our responses to the
comments. Based on these changes, we have reassessed our proposed
action on the State's NOX BART determinations for each of
the subject-to-BART sources by re-evaluating the five statutory
factors.\16\ We have also reassessed our proposed action on the State's
NOX reasonable progress determination for Dave Johnston
Units 1 and 2. In this section, we describe in detail our reassessment
of the statutory factors for these sources based on our revised
visibility modeling and cost estimates. For two sources--Jim Bridger
and Wyodak--we also received additional comments, explained below, that
caused us to
[[Page 5047]]
reconsider certain aspects of our decision for those sources.
---------------------------------------------------------------------------
\16\ We are finalizing our proposed approval of the State's PM
BART determinations. We did not receive any adverse comments that
were sufficient to convince us that reexamination of the State's
control costs was warranted.
---------------------------------------------------------------------------
EPA notes that, in considering the visibility improvements
reflected in our revised modeling, EPA interprets the BART Guidelines
to require consideration of the visibility improvement from BART
applied to the entire BART-eligible source. The BART Guidelines explain
that, ``[i]f the emissions from the list of emissions units at a
stationary source exceed a potential to emit of 250 tons per year for
any visibility-impairing pollutant, then that collection of emissions
units is a BART-eligible source.'' In other words, the BART-eligible
source (the list of BART emissions units at a source) is the collection
of units for which one must make a BART determination. The BART
Guidelines state ``you must conduct a visibility improvement
determination for the source(s) as part of the BART determination.''
This requires consideration of the visibility improvement from BART
applied to the BART-eligible source as a whole.
We note, however, that while our regulations require states and EPA
to assess visibility improvement on a source-wide basis, they provide
flexibility to also consider unit-specific visibility improvement in
order to more fully inform the reasonableness of a BART determination,
but that does not replace the consideration of visibility benefit from
the source (facility) as a whole. In making the BART determinations in
this final action we have considered visibility improvements at the
source, and then also at the units that comprise the source.
As explained in more detail later in this decision, we received
during the comment period significant input on expected costs
associated with different control technologies. We discuss in the
section above and in our response to comments, the changes we made in
response to comments received on costs of different control
technologies. As discussed above and in our response to comments, we
have revised our modeling analysis in light of the input we received
during the public comment period. This additional information and
analysis result in different costs and visibility benefits, two of the
five BART factors. In some cases this leads us to finalize our
proposal, and in other cases to reach a different conclusion.
This decision, which addresses multiple facilities in a state where
numerous Class 1 areas are impacted to a greater or lesser degree,
illustrates clearly the case-by-case nature of the BART determination
process. The interplay among the five factors, and in particular the
cost and visibility factors, is highly significant and determinative of
the outcome. In considering this information, as we have noted in prior
decisions, our first assessment is whether the state's determination is
reasonable in light of the facts and consistent with the requirements
of the Clean Air Act and implementing regulations. If we determine that
it is, even if we might have reached a different outcome if it were our
decision to make in the first instance, we will approve the SIP.
Below is a more specific discussion of our determinations in the
final decision. As stated above more detailed information on our
determinations can be found in the response to comments sections of
this rulemaking.
A. Laramie River
The State's regional haze SIP determined that NOX BART
for Laramie River Units 1, 2, and 3 is new LNB/SOFA. We proposed to
disapprove the State's determination because the State neglected to
reasonably assess the costs of compliance and visibility improvement in
accordance with the BART Guidelines. 78 FR 34766. After revising the
State's costs and modeling and re-evaluating the statutory factors, we
proposed to determine that NOX BART is LNB/SOFA + SCR, with
an emissions limit of 0.07 lb/MMBtu for each unit. We sought comment
generally on the BART factors and our control determinations and
indicated that we could revise our control determinations depending on
any new information that we received.
As the result of the comments received on our proposal, we have
further revised our calculation of the costs of compliance and
visibility modeling. We have considered any comments on the other BART
factors but we have not changed our assessment of the other BART
factors. The revised visibility modeling for the most impacted Class I
area (Badlands) is presented in the following table.
Table 18--Visibility Modeling for Laramie River Station
----------------------------------------------------------------------------------------------------------------
Laramie River Station LNB/SOFA LNB/SOFA + SNCR LNB/SOFA + SCR
----------------------------------------------------------------------------------------------------------------
Unit 1............................. 0.18 deciviews....... 0.28 deciviews....... 0.57 deciviews
Unit 2............................. 0.18 deciviews....... 0.27 deciviews....... 0.53 deciviews
Unit 3............................. 0.18 deciviews....... 0.27 deciviews....... 0.52 deciviews
----------------------------------------------------------------------------
Total *........................ 0.54 deciviews....... 0.82 deciviews....... 1.62 deciviews
----------------------------------------------------------------------------------------------------------------
* The total visibility improvement was estimated as the sum of the visibility improvement from each unit.
We also considered the visibility improvement at other impacted
Class I areas (Wind Cave, Rawah, and Rocky Mountain), which range from
0.25 to 0.47 deciviews, 0.26 to 0.43 deciviews, and 0.23 to 0.44
deciviews, for Units 1, 2, and 3, respectively. Further details
regarding our revised visibility modeling and cost estimates were
provided in section III.A.
After re-evaluating the BART factors, we continue to find that LNB/
SOFA + SCR is reasonable as BART and are therefore finalizing our
proposal. The visibility improvement associated with LNB/SOFA + SCR at
the most impacted Class I area is significant on both a source-wide
(1.62 deciviews) and unit-specific (0.52-0.57 deciviews) basis. The
significant visibility improvement at three other impacted Class I
areas also supports the selection of this option. Finally, we believe
that the incremental visibility improvement at the most impacted Class
I area of SCR over SNCR (nearly double in all cases) warrants the
selection of the most stringent control.
In regards to the costs of compliance, we found that the revised
average and incremental cost-effectiveness of LNB/SOFA + SCR is in line
with what we have found to be acceptable in our other FIPs. The average
cost-effectiveness per unit ranges from $4,375 to $4,461/ton, while the
incremental cost-effectiveness ranges from $5,449 to $5,871/ton. We
believe that these costs are reasonable, especially in light of the
significant visibility improvement associated with LNB/SOFA + SCR. As a
result, we are finalizing our proposed disapproval of the State's
NOX BART determination for Laramie River Station and
finalizing our proposed FIP that includes a NOX BART
determination of LNB/SOFA + SCR,
[[Page 5048]]
with an emission limit of 0.07 lb/ MMBtu (30-day rolling average).
B. Jim Bridger
The State's regional haze SIP determined that NOX BART
for Jim Bridger Units 1-4 is new LNBs with SOFA. The State also
determined that SCR should be installed at each unit as part of the
State's long-term strategy to achieve reasonable progress at several
Class I areas, and set compliance dates of December 31, 2022, December
31, 2021, December 31, 2015, and December 31, 2016 for Units 1-4,
respectively.
In our proposal, we indicated that the State had neglected to
reasonably assess the costs of compliance and visibility improvement
for Jim Bridger in accordance with the BART Guidelines. We nonetheless
proposed to approve the State's BART and reasonable progress
determinations for Units 3 and 4 because the compliance deadlines to
install SCR on these units were sufficient to meet the requirements of
BART. We are now finalizing our proposed action for Units 3 and 4.
We also proposed to approve the State's BART and reasonable
progress determinations for Units 1 and 2, but on a different basis.
There, we indicated that given the number of SCR retrofits PacifiCorp
had to perform in Wyoming and in other states, it might not be
affordable for PacifiCorp to install two additional SCRs on Jim Bridger
Units 1 and 2 within the five-year BART compliance period. We requested
additional information from commenters regarding whether the
affordability provisions of the BART Guidelines should be applied to
Units 1 and 2. In the alternative, we proposed to find that
NOX BART for Units 1 and 2 was an emission limit of 0.07 lb/
MMBtu (30-day rolling average) based on the installation of LNB/SOFA +
SCR with a compliance deadline of five years. Under this scenario, we
acknowledged that the cost-effectiveness of LNB/SOFA + SCR at Units 1
and 2 was within the range of what EPA and the State itself had found
reasonable in other BART determinations. We also considered the
significant visibility improvement demonstrated by the State's modeling
to warrant LNB/SOFA + SCR as BART. Finally, we sought comment generally
on the BART factors and our control determinations and indicated that
we could revise our control determinations depending on any new
information that we received.
In response to our proposal, we received both supportive and
adverse comments regarding whether the affordability provisions of the
BART Guidelines should apply to Units 1 and 2. As explained in more
detail in our responses to these comments, we agree that PacifiCorp did
not make a sufficient showing that it could not afford to install LNB/
SOFA + SCR on Units 1 and 2 within the five-year compliance period.
Nevertheless, we also received new information regarding the costs of
compliance and visibility benefits associated with Jim Bridger and have
revised our cost estimates and visibility modeling for all four units
accordingly. We have considered any comments on the other BART factors
but we have not changed our assessment of the other BART factors.
The revised visibility modeling for the most impacted Class I area
(Bridger) is presented in the following table (with straight font
representing modeled results using an ammonia background based on a
monitored monthly varying concentration, italicized font representing
modeled results using IWAQM default 0.5 ppb background ammonia).\17\
---------------------------------------------------------------------------
\17\ Air Quality Modeling Protocol: Wyoming Regional Haze
Federal Implementation Plan, U.S. EPA, January, 2014.
Table 19--Visibility Modeling for Jim Bridger
----------------------------------------------------------------------------------------------------------------
Jim Bridger LNB/SOFA LNB/SOFA + SNCR LNB/SOFA + SCR
----------------------------------------------------------------------------------------------------------------
Unit 1.......................... 0.17/0.23 deciviews 0.20/0.27 deciviews 0.27/0.37 deciviews
Unit 2.......................... 0.16/0.21 deciviews 0.19/0.25 deciviews 0.27/0.36 deciviews
Unit 3.......................... 0.14/0.19 deciviews 0.17/0.23 deciviews 0.26/0.35 deciviews
Unit 4.......................... 0.25/0.23 deciviews 0.30/0.28 deciviews 0.45/0.42 deciviews
-------------------------------------------------------------------------------
Total *..................... 0.72/0.86 deciviews 0.86/1.03 deciviews 1.25/1.5 deciviews
----------------------------------------------------------------------------------------------------------------
* The total visibility improvement was estimated as the sum of the visibility improvement from each unit.
We also considered the visibility improvements at other impacted
Class I areas (Bridger, Fitzpatrick, Rawah, Rocky Mountain, Grand
Teton, Teton, Washakie, and Yellowstone), which range from 0.26 to 0.91
deciviews, 0.26 to 0.89 deciviews, 0.24 to 0.87 deciviews, and 0.27 to
1.0 deciviews, for Units 1-4, respectively. Further details regarding
our revised visibility modeling and cost estimates are provided in
section III.A.
After re-evaluating the BART factors, we are approving the State's
determination that LNB/SOFA is NOX BART for Units 1-4. The
visibility improvement associated with LNB/SOFA + SCR at the most
impacted Class I area is significant on a source-wide basis (1.25 to
1.5 deciviews). The fact that Jim Bridger Station affects a number of
other Class I areas, which also would see appreciable visibility
improvement with the installation of LNB/SOFA + SCR, also weighs in
favor of selecting this option as BART. The unit-specific benefits for
Units 1 and 2 are somewhat more modest (0.27-0.37 deciviews), however,
especially considering the low incremental improvement over SNCR (0.07-
0.11 deciviews). The incremental visibility improvement of SNCR over
LNB/SOFA is even smaller (0.03-0.04 deciviews).
In regards to the costs of compliance, we found that the revised
average cost-effectiveness of LNB/SOFA + SCR is in line with what we
have found to be acceptable in our other FIPs. The average cost-
effectiveness is $4,088 and $4,461/ton at Units 1 and 2, respectively.
The incremental cost-effectiveness, on the other hand, is on the high
end of what we have found to be reasonable in our other FIPs. The
incremental cost-effectiveness is $7,477 and $8,986/ ton at Units 1 and
2, respectively.
Ultimately however, while we believe that these costs and
visibility improvements could potentially justify LNB/SOFA + SCR as
BART, because this is a close call and because the State has chosen to
require SCR as a reasonable progress control, we believe deference to
the State is appropriate in this instance. We are therefore finalizing
[[Page 5049]]
our approval of the State's determination to require SCR at Jim Bridger
Units 1-4, with an emission limit of 0.07 lb/MMBtu (30-day rolling
average), as part of its long-term strategy. We are also finalizing our
approval of the compliance dates of December 31, 2022, December 31,
2021, December 31, 2015, and December 31, 2016 for Units 1- 4
respectively.
C. Dave Johnston Units 3 and 4
The State's regional haze SIP determined that NOX BART
for Dave Johnston Units 3 and 4 is LNB/OFA. We proposed to disapprove
the State's determination because the State neglected to reasonably
assess the costs of compliance and visibility improvement in accordance
with the BART Guidelines. 78 FR 34778. After revising the State's costs
and modeling and re-evaluating the statutory factors, we proposed to
determine that NOX BART for Unit 3 is LNB/SOFA + SCR, with
an emission limit of 0.07 lb/ MMBtu (30-day rolling average). We
proposed that NOX BART for Unit 4 is LNB/SOFA + SNCR, with
an emission limit of 0.12 lb/ MMBtu. We sought comment generally on the
BART factors and our control determinations and indicated that we could
revise our control determinations depending on any new information that
we received.
As the result of the comments received on our proposal, we have
further revised our calculation of the costs of compliance and
visibility modeling. We have considered any comments on the other BART
factors but we have not changed our assessment of the other BART
factors. The revised visibility modeling for the most impacted Class I
area (Wind Cave) is presented in the following table.
Table 20--Visibility Modeling for Dave Johnston (BART Units)
----------------------------------------------------------------------------------------------------------------
Dave Johnston LNB/OFA LNB/OFA + SNCR LNB/OFA + SCR
----------------------------------------------------------------------------------------------------------------
Unit 3............................. 0.33 deciviews....... 0.39 deciviews....... 0.51 deciviews
Unit 4............................. 0.41 deciviews....... 0.46 deciviews....... 0.57 deciviews
----------------------------------------------------------------------------
Total *........................ 0.74 deciviews....... 0.85 deciviews....... 1.08 deciviews
----------------------------------------------------------------------------------------------------------------
* The total visibility improvement was estimated as the sum of the visibility improvement from each unit.
We also considered the visibility improvement at other impacted
Class I areas (Badlands, Mt Zirkel, Rawah, and Rocky Mountain), which
range from 0.20 to 0.47 deciviews and 0.24 to 0.55 deciviews, for Units
3 and 4, respectively. Further details regarding our revised visibility
modeling and cost estimates were provided in section III.A.
After re-evaluating the BART factors, we no longer believe that
LNB/OFA + SNCR is NOX BART for Dave Johnston Unit 4. As we
explained in the proposal, the incremental cost-effectiveness of LNB/
OFA + SCR was and continues to be excessive ($13,312), so we have
eliminated this control option. While the revised average and
incremental costs of LNB/OFA + SNCR continue to be reasonable, the
incremental visibility improvement of SNCR over LNB/OFA is now only
0.05 deciviews. In light of this new visibility information, we believe
that the State's determination that LNB/OFA is NOX BART for
Unit 4 was reasonable and are approving it accordingly.
In regards to Dave Johnston Unit 3, we continue to believe that
LNB/OFA + SCR is NOX BART. The visibility improvement
associated with LNB/SOFA + SCR at the most impacted Class I area is
significant (0.51 deciviews). The visibility improvement at several
other impacted Class I areas also supports the selection of this
option. Finally, we do not believe that the incremental visibility
improvement at the most impacted Class I area of SCR over SNCR (0.12
deciviews) is sufficiently insignificant to warrant the elimination of
the most stringent control in this instance.
In regards to the costs of compliance, we found that the revised
average and incremental cost-effectiveness of LNB/SOFA + SCR is in line
with what we have found to be acceptable in our other FIPs. The average
cost-effectiveness is $2,635/ton, while the incremental cost-
effectiveness is $7,583/ton. We believe that these costs are
reasonable, especially in light of the significant visibility
improvement associated with LNB/SOFA + SCR.
In response to other comments we received, we also considered an
alternative BART analysis for Unit 3 based on PacifiCorp's commitment
to retire Unit 3 by 2027 in lieu of installing SCR. Using a 9-year
remaining useful life as the amortization period for Unit 3, the
incremental cost-effectiveness of LNB/OFA + SCR becomes excessive
($11,781). Furthermore, the incremental visibility improvement at the
most impacted Class I area from use of LNB/OFA to use of LNB/OFA+ SNCR
is only 0.06 deciviews. Thus, taking all five factors into account,
including the remaining useful life of nine years, we conclude that the
NOX BART would be LNB/OFA in this scenario.
To provide flexibility, we are finalizing both scenarios in a FIP
for Dave Johnston Unit 3. Under the first scenario, we are finalizing a
NOX BART determination of LNB/OFA + SCR, with an emission
limit of 0.07 lbs/ MMBtu (30-day rolling average). Under the
alternative scenario, based on a commitment to retire Unit 3 by 2027,
we are finalizing a NOX BART determination of LNB/OFA, with
an emission limit of 0.28 lbs/ MMBtu (30-day rolling average).
D. Naughton
The State's regional haze SIP determined that NOX BART
is new LNB/OFA for Naughton Units 1 and 2 and LNB/OFA + SCR for
Naughton Unit 3. We proposed to approve the State's determination for
Unit 3, but proposed to disapprove the State's determination for Units
1 and 2 because the State neglected to reasonably assess the costs of
compliance and visibility improvement in accordance with the BART
Guidelines. 78 FR 34748. After revising the State's costs and modeling
and re-evaluating the statutory factors, we proposed to determine that
NOX BART for Units 1 and 2 is LNB/SOFA + SCR, with an
emissions limit of 0.07 lb/MMBtu for each unit. We sought comment
generally on the BART factors and our control determinations and
indicated that we could revise our control determinations depending on
any new information that we received.
As the result of the comments received on our proposal, we have
further revised our calculation of the costs of compliance and
visibility modeling. We have considered any comments on the other BART
factors but we have not changed our assessment of the other BART
factors. The revised visibility modeling for the most impacted Class I
area (Bridger) is presented in the following table (with straight font
representing modeled
[[Page 5050]]
results using an ammonia background based on a monitored monthly
varying concentration, italicized font representing modeled results
using IWAQM default 0.5 ppb background ammonia).
Table 21--Visibility Modeling for Naughton
----------------------------------------------------------------------------------------------------------------
Naughton LNB/OFA LNB/OFA + SNCR LNB/OFA + SCR
----------------------------------------------------------------------------------------------------------------
Unit 1............................... 0.22/0.26 deciviews.... 0.26/0.30 deciviews.... 0.33/0.39 deciviews.
Unit 2............................... 0.28/0.32 deciviews.... 0.34/0.38 deciviews.... 0.42/0.46 deciviews.
Unit 3............................... 0.05/0.07 deciviews.... 0.20/0.29 deciviews.... 0.49/0.60 deciviews.
--------------------------------------------------------------------------
Total *.......................... 0.55/0.65 deciviews.... 0.80/0.97 deciviews.... 1.24/1.45 deciviews
----------------------------------------------------------------------------------------------------------------
* The total visibility improvement was estimated as the sum of the visibility improvement from each unit.
We also considered the visibility improvement at other impacted
Class I areas (Fitzpatrick, North Absaroka, Washakie, Teton, Grand
Teton, and Yellowstone), which range from 0.10 to 0.30 deciviews, 0.08
to 0.42 deciviews, and 0.13 to 0.49 deciviews, for Units 1, 2, and 3,
respectively. Further details regarding our revised visibility modeling
and cost estimates were provided in section III.A.
After re-evaluating the BART factors, we no longer believe that
LNB/OFA + SCR is NOX BART for Naughton Units 1 and 2. The
visibility improvement associated with LNB/SOFA + SCR at the most
impacted Class I area remains significant on a source-wide basis (1.24-
1.45 deciviews) but more modest on a unit-specific basis (0.33-0.46
deciviews). The visibility improvement at six other impacted Class I
areas continues to support the selection of this option as well. In
regards to the costs of compliance, however, we found that while the
revised average cost-effectiveness values for LNB/OFA + SCR were
acceptable, the revised incremental cost-effectiveness values were
beyond the upper end of the range (higher even than Jim Bridger) of
what we have found to be acceptable in our other FIPs. For Units 1 and
2, respectively, the average cost-effectiveness per unit is $3,109 and
$2,566/ ton, while the incremental cost-effectiveness is $10,384 and
$8,440/ ton. Consequently, we believe that it was not unreasonable for
the State to reject LNB/OFA + SCR as BART. Furthermore, we cannot say
the State acted unreasonably in rejecting LNB/OFA + SNCR at Units 1 and
2 because the incremental visibility improvement of SNCR over LNB/OFA,
while possibly appreciable, is very low at just 0.10 deciviews across
both units. Therefore, based on our analysis we believe that the
State's determination that LNB/OFA is NOX BART for Units 1
and 2, with an emission limit of 0.28 lbs/ MMBtu, was ultimately
reasonable and are approving it accordingly.
E. Wyodak
The State's regional haze SIP determined that NOX BART
for Wyodak Unit 1 is new LNBs with OFA. We proposed to disapprove the
State's determination because the State neglected to reasonably assess
the costs of compliance and visibility improvement in accordance with
the BART Guidelines. 78 FR 34784-34785. As a result, we also proposed a
FIP for NOX BART. After considering the BART factors, we
noted that the cost-effectiveness and visibility improvement of the
most stringent control option, LNB/OFA + SCR, were within the range of
values that EPA had found reasonable in other FIPs. However, we
proposed not to require LNB/OFA + SCR as NOX BART for Wyodak
Unit 1. Instead, we proposed to require LNB/OFA + SNCR based on the
reasoning that the cumulative visibility improvement of SCR across all
Class I areas was low when compared to the cumulative visibility
improvement associated with SCR at Dave Johnston Unit 3, Laramie River
Units 1-3, and Naughton Units 1 and 2. We sought comment generally on
the BART factors and our control determinations and indicated that we
could revise our control determinations depending on any new
information that we received. Based on our discussion of LNB/OFA + SCR
at Wyodak, that control option was among those that we invited comment
on.
In response to our proposal for Wyodak, we received comments that
cumulative visibility improvement should not be used as a basis to
reject a control option that has already been deemed reasonable based
on visibility improvement at the most impacted Class I area. The
commenters pointed out that such an approach would have the illogical
effect of allowing an added benefit (visibility improvement at multiple
Class I areas) to weigh in favor of less stringent controls. We agree
with this criticism and want to make clear today that where a control
is warranted as BART based on the costs of controls and visibility
benefits at the most impacted area alone, cumulative visibility
benefits can only strengthen the case for that control, not suggest
that it is unwarranted. Similarly, where a control might not be
warranted as BART based on the improvement at a single Class I area,
significant cumulative benefits are an additional consideration that
could warrant that the control be selected as BART.
In addition, we have further revised our calculation of the costs
of compliance and visibility modeling for Wyodak Unit 1. We have not
changed our assessment of the other BART factors. The revised
visibility modeling for the most impacted Class I area (Wind Cave) is
presented in the following table.
Table 22--Visibility Modeling for Wyodak
----------------------------------------------------------------------------------------------------------------
Wyodak LNB/SOFA LNB/SOFA + SNCR LNB/SOFA + SCR
----------------------------------------------------------------------------------------------------------------
Unit 1............................. 0.21 deciviews....... 0.32 deciviews....... 0.61 deciviews.
----------------------------------------------------------------------------------------------------------------
We also considered the visibility improvement at a second impacted
Class I area (Badlands), which is a maximum of 0.38 deciviews for LNB/
SOFA + SCR. Further details regarding our revised visibility modeling
and cost estimates were provided in the previous section.
[[Page 5051]]
After re-evaluating the BART factors and dismissing our earlier
rationale for rejecting an otherwise reasonable control, we find that
LNB/SOFA + SCR is reasonable as BART. As the BART-eligible source in
this case is a single unit, the source-wide and unit-specific
visibility improvements associated with the various control options are
the same. The visibility improvement associated with LNB/SOFA + SCR at
the most impacted Class I area (0.61 deciviews) is significant. There
is also a more modest visibility improvement (0.38 deciviews) at a
second impacted Class I area that supports the selection of this
option. Finally, we believe that the incremental visibility improvement
at the most impacted Class I area of SCR over SNCR (nearly double)
warrants the selection of the most stringent control.
In regards to the costs of compliance, we found that the revised
average and incremental cost-effectiveness of LNB/SOFA + SCR is in line
with what we have found to be acceptable in our other FIPs. The average
cost-effectiveness is $4,036/ton, while the incremental cost-
effectiveness of SCR over SNCR is $6,223/ton. We believe that these
costs are reasonable, especially in light of the significant visibility
improvement associated with LNB/SOFA + SCR at Wind Cave. As a result,
we are finalizing our proposed disapproval of the State's
NOX BART determination for Wyodak Unit 1. Additionally,
after carefully considering adverse comments, we have decided not to
finalize our proposed NOX determination of LNB/SOFA + SNCR,
but rather are finalizing a NOX BART determination of LNB/
SOFA + SCR, with an emission limit of 0.07 lb/ MMBtu (30-day rolling
average).
F. Dave Johnston Units 1 and 2 (Reasonable Progress)
We proposed to disapprove the State's determination to not impose
LNB/OFA as reasonable progress controls for NOX at Dave
Johnston Units 1 and 2. Based on our original cost estimates and
visibility modeling, we also proposed to require PacifiCorp Dave
Johnston Units 1 and 2 to meet a FIP emission limit of 0.22 lb/MMBtu
(30-day rolling average) (assuming the installation of LNB/OFA). Based
on our revised cost estimates and visibility modeling that we developed
in response to comments, however, we no longer conclude that reasonable
progress controls are warranted this planning period. While we continue
to disagree with the State's reasoning for not imposing controls (as
detailed in our response to comments), we are not prepared to say the
State's ultimate decision was unreasonable. In evaluating the four
reasonable progress factors and the visibility improvement associated
with potential controls, we found that the average and incremental
cost-effectiveness of LNB/OFA ($990/ton and $1,221/ton, respectively),
while reasonable if viewed in isolation, was not necessarily justified
this planning period in light of the relatively modest visibility
improvement predicted by the revised modeling (0.11 deciviews--0.12
deciviews at the most impacted Class I area). As a result, we are
approving the State's reasonable progress determination of no new
controls for Dave Johnston Units 1 and 2, but we expect the State to
revisit the issue during the next planning period.
V. Issues Raised by Commenters and EPA's Responses
A. Legal Issues
1. EPA Authority and State Discretion
Comment: Multiple commenters stated that CAA Section 169A and the
Regional Haze Rule (RHR) give the states the lead in developing their
regional haze SIPs. Some commenters went further in stating that
Wyoming is given almost complete discretion in creating its regional
haze SIP. These commenters argued that, because Wyoming is given such
discretion, EPA lacks the statutory authority to disapprove the State's
regional haze SIP. Specifically, some commenters pointed to the
flexibility the State is granted in developing its BART determinations
and other RHR requirements. The commenters stated that the CAA
anticipates that EPA will create guidance and that the states, using
their discretion, will use this guidance to develop regional haze SIPs.
The State of Wyoming and other parties argued that each factor in the
five-factor analysis used to make its BART determinations was
appropriately weighed based on the State's own discretion. The
commenters therefore argue that EPA has no basis on which to disapprove
the five-factor analysis and that EPA does not have authority to reject
a state's BART determination solely because EPA would have conducted
the analysis in a different way or reached a different conclusion. The
commenters went on to say that the State, after considering all
statutory factors, made BART determinations for all subject-to-BART
sources in a manner consistent with 40 CFR Part 51 Appendix Y, the
established CAA requirements, and the interests of the State of
Wyoming.
Numerous commenters went on to say that the U.S. Court of Appeals
for the D.C. Circuit has affirmed that EPA's role in determining BART
is limited and that a state's role is paramount. The court found that
the CAA ``calls for states to play the lead role in designing and
implementing regional haze programs.'' Am. Corn Growers Ass'n v. EPA,
291 F.3d 1, 2 (D.C. Cir. 2002). The commenters stated that the court
also reversed a portion of EPA's original RHR because it found that
EPA's method of analyzing visibility improvements distorted the
statutory BART factors and was ``inconsistent with the Act's provisions
giving the states broad authority over BART determinations.'' Id., see
also Utility Air Regulatory Group v. EPA, 471 F.3d 1333, 1336 (D.C.
Cir. 2006) (The second step in a BART determination ``requires states
to determine the particular technology that an individual source
`subject to BART' must install.'').
The commenters asserted that states have the primary responsibility
for preventing air pollution under the CAA. CAA section 101(a)(3), 42
U.S.C. 7401(a)(3). Pursuant to this principle, states, not EPA, have
always had primary control over decisions to impose specific emission
limits (and therefore specific pollution control technologies) for
individual facilities. By congressional design, EPA ``is relegated . .
. to a secondary role in the process of determining and enforcing the
specific, source-by-source emission limitations which are necessary [to
meet] national standards.'' Train v. NRDC, 421 U.S. 60, 79 (1975). This
basic division of responsibilities between EPA and the states remained
unchanged when Congress amended the Act in 1977 and again in 1990. See
Virginia v. EPA, 108 F.3d 1397, 1408-09 (D.C. Cir. 1997).
Response: Congress crafted the CAA to provide for states to take
the lead in developing SIPs, but balanced that decision by requiring
EPA to review the SIPs to determine whether they meet the requirements
of the CAA. EPA's review of SIPs is not limited to a ministerial type
of automatic approval of a state's decisions. See North Dakota v. EPA,
730 F.3d 750, 760-61 (8th Cir. 2013) (``Although the CAA grants states
the primary role of determining the appropriate pollution controls
within their borders, EPA is left with more than the ministerial task
of routinely approving SIP submissions.'') (hereinafter ``North
Dakota''). EPA must consider not only whether the State considered the
appropriate factors, but whether the State acted reasonably in doing
so. In undertaking such a review, EPA does not ``usurp'' the State's
authority, but ensures that such authority is reasonably exercised. EPA
has the authority to issue a FIP either
[[Page 5052]]
when EPA has made a finding that the state has failed to timely submit
a SIP or when EPA has found a SIP deficient. Here, EPA has authority on
both grounds, and we have approved as much of the Wyoming regional haze
SIP as possible, while promulgating a FIP only to fill the remaining
gaps. Our action today is consistent with the statute.
Our action does not contradict the Supreme Court's decision in
Train. States have significant responsibilities in the implementation
of the CAA and meeting the requirements of the RHR. We recognize that
states have the primary responsibility of drafting a SIP to address the
requirements of the CAA's visibility program. We also recognize that we
have the responsibility of ensuring that SIPs, including regional haze
SIPs, conform to CAA requirements. We cannot approve a regional haze
SIP that fails to address BART with a reasoned consideration of the
statutory and regulatory requirements of the CAA and the RHR. See
Oklahoma v. EPA, 723 F.3d 1201, 1207 (10th Cir. 2013) (``We agree with
the EPA that the statute provides the agency with the power to review
Oklahoma's BART determination for these four units.'') (hereinafter
``Oklahoma'').
Contrary to the commenters' assertions, we recognize the State's
primary responsibility in drafting a SIP. In fact, we have approved
many of the State's determinations, including the entirety of Wyoming's
Section 309 BART alternative for SO2 emissions. We are
disapproving the State's NOX BART determinations, as the CAA
requires, because the State neglected to properly consider the costs of
compliance and the visibility benefits associated with several of the
available control options.
We also disagree that our proposal is inconsistent with the
American Corn Growers and Utility Air Regulatory Group decisions. These
cases dealt with EPA's authority to issue broad regulations that
prescribed how states must conduct their BART determinations. They did
not address EPA's authority to review regional haze SIPs for compliance
with the mandates of the CAA or EPA's now finalized implementing
regulations. The Tenth Circuit, in concluding that EPA had authority to
disapprove a BART determination that did not follow the BART
Guidelines, stated that the American Corn Growers opinion ``does not
alter this conclusion.'' Oklahoma v. EPA, 723 F.3d 1201, 1208 (10th
Cir. 2013).
Because the CAA sets certain mandatory statutory deadlines and
provides for citizen suits when the Administrator fails to perform a
mandatory duty, we are required by the terms of a consent decree to
ensure that Wyoming's CAA requirements for regional haze are finalized
by January 10, 2014. Because we have found that the State's regional
haze SIP did not satisfy CAA and RHR requirements in full and because
we have previously found that Wyoming failed to timely submit its
regional haze SIP, we have not only the authority, but a statutory duty
to promulgate a FIP that meets those requirements. We have reviewed
this decision in light of other decisions made by us, as well as
decisions made in other states SIPs. Our action today in large part
approves the regional haze SIP submitted by Wyoming. Our disapproval of
Wyoming's NOX BART and reasonable progress determinations
and imposition of a FIP is not intended to encroach on State authority.
Rather, our action today is required by the CAA to ensure that the
State has a complete plan in place to address the CAA's visibility
requirements.
Comment: The fact that Congress gave states primacy in making BART
determinations is noteworthy and related to the fact that the regional
haze program is focused on an aesthetic benefit, not a public health
standard. Under other sections of the CAA, primarily those dealing with
health-based standards, Congress directed EPA to establish standards
that do not take costs into consideration. States then develop plans to
meet those health-based standards. Under the New Source Performance
Standards program (section 111 of the CAA) and National Emission
Standards for Hazardous Air Pollutants program (section 112), EPA
routinely establishes specific emission limits for large industrial
sources. The regional haze program, which deals with an aesthetic
standard, was clearly laid out by Congress to be different in its
approach, to avoid establishing emission limits, to give states
authority to decide appropriate controls, and allow states to weigh the
costs against the benefits.
Response: We do not agree with this commenter's characterization of
the regional haze program or the CAA's visibility requirements. While
it is true that the goal of CAA sections 169A and 169B is to improve
visibility in national parks and wilderness areas rather than to
prevent adverse human health effects, Congress structured the program
so that states' decisions had to be made in the form of SIPs, which EPA
has the authority to review for compliance with all CAA requirements.
Furthermore, Congress did not create an approach that would allow
states to avoid establishing emission limits. On the contrary, Congress
specifically directed EPA's regulations to require states to devise
``emission limits . . . necessary to make reasonable progress,'' CAA
section 169A(b)(2), including the requirement to establish BART, which
the RHR defines as ``an emission limitation.'' 40 CFR 51.301.
Comment: EPA's actions leave nothing under the CAA's framework by
which Wyoming could make an approvable BART determination. EPA has
overreached and exceeded its statutory authority by proposing a FIP
that replaces Wyoming's considered judgment with EPA's priorities and
policy choices.
Response: We disagree with this comment. EPA is not substituting
its judgment for that of the State of Wyoming or issuing a FIP merely
to advance priorities and policy choices. Rather, we have determined
that Wyoming did not properly follow the BART Guidelines or the CCM in
conducting its BART analyses and, therefore, did not correctly consider
the costs of compliance or the visibility benefits associated with
available control technologies as the CAA requires. Consequently, we
are finalizing a FIP in today's action to remedy the gaps left by these
inadequacies. We note, however, that the CAA's framework provides
Wyoming with the opportunity to submit a SIP revision at any time that
could replace all or a portion of EPA's FIP, and we encourage Wyoming
to do so.
Comment: EPA clearly gave the states more discretion through
rulemaking when it split the universe of BART sources impacted by the
BART Guidelines into power plants greater than 750 megawatts (MW) and
all others. States were merely encouraged to follow the BART Guidelines
for the smaller BART sources. EPA says in the preamble ``that states
should view the guidelines as helpful guidance for these other
categories.'' In saying this, EPA is affording even more discretion to
the states in making BART determinations for the smaller BART sources.
EPA has proposed disapproval of Wyoming's BART determination and
proposed a FIP for one of these smaller sources, the Wyodak Unit 1 335
MW power plant. The State believes that the EPA is again overreaching
in its action by proposing a FIP for Wyodak Unit 1, where Wyoming was
not even required to follow the BART Guidelines in arriving at its BART
determination.
Response: We agree that the BART Guidelines are only mandatory for
[[Page 5053]]
``fossil-fuel fired power plants having a total generating capacity
greater than 750 megawatts.'' 40 CFR 51.308(e)(1)(ii)(B). However, the
fact that a state may deviate from the procedures in the BART
Guidelines when selecting BART for smaller EGUs does not mean that a
state has unfettered discretion to act unreasonably or inconsistently
with the CAA or the RHR. Ultimately, a state must still adopt the
``best available retrofit technology,'' CAA section 169A(b)(2)B); 40
CFR 51.308(e)(1)(ii)(A), while reasonably considering the five
statutory factors.
The RHR further defines BART to mean ``an emission limitation based
on the degree of reduction achievable through the application of the
best system of continuous emission reduction for each pollutant which
is emitted by an existing stationary facility.'' 40 CFR 51.301
(emphasis added). We do not interpret this requirement to allow a state
to dismiss the best system of continuous emission reduction under the
mantle of unlimited state discretion. As we discuss elsewhere in this
document, Wyoming erroneously evaluated costs and visibility benefits
when analyzing the various control options available for Wyodak, and
thereby did not reasonably consider the statutory factors and select
the best system of control.
Comment: EPA's RHR gave states the flexibility to choose
alternatives to the BART process, such as participation in a trading
program. EPA spells out in the preamble that this ``substantial
flexibility'' provides the ``states the ability to choose the least
costly and least burdensome alternative.'' EPA and 28 states on the
east coast took advantage of this flexibility when it declared that the
cap and trade program for ozone nonattainment would, for the most part,
satisfy the requirements of BART. The important point here is that EPA
wanted and pushed for flexible, cost-savings approaches to address
regional haze. EPA is still pushing for approval of the Cross States
Air Pollution Rule (CSAPR) as a solution to regional haze problems on
the east coast.
There appears to be a consistency issue within the EPA over the
application of flexibility. Wyoming does not think EPA meant for an
approach to promote costs savings and less burdensome solutions to be
restricted to one area of the country or certain types of solutions.
However, EPA's proposal to partially disapprove Wyoming's regional haze
SIP and impose more costly and burdensome FIP requirements for seven
BART units in the State of Wyoming appear to be inconsistent with EPA's
purported ``substantial flexibility.'' EPA's failure to recognize
Wyoming's discretion in these areas is arbitrary and capricious.
Response: Wyoming had the opportunity to submit better-than-BART
alternatives in lieu of source-specific NOX BART
determinations. Wyoming did not do so. Because Wyoming did not take
advantage of the flexibility afforded by better-than-BART alternatives,
we must review Wyoming's BART determinations for compliance with the
applicable requirements of the CAA, RHR, and BART Guidelines. Our
proposal clearly laid out the bases for our proposed disapproval of the
State's NOX BART determinations, and we have relied on the
standards contained in our regulations and the authority that Congress
granted us to review and determine whether Wyoming's regional haze SIP
complied with the minimum statutory and regulatory requirements. To the
extent a cost analysis relies on values that are inaccurate, a state
has not considered cost in a reasoned or reasonable fashion. To the
extent a state has considered visibility improvement from potential
emissions controls in a way that substantially understates the
improvement or does so in a way that is not consistent with the CAA,
the state has not considered visibility improvement in a reasoned or
reasonable fashion. In these circumstances--as discussed in more detail
in the proposed notice and this final notice--EPA is required to
disapprove the relevant aspects of the SIP. In determining SIP
adequacy, we must exercise our judgment and expertise regarding complex
technical issues, and it is entirely appropriate that we do so. Courts
have recognized this necessity and deferred to our exercise of
discretion when reviewing SIPs. See, e.g., Connecticut Fund for the
Env't., Inc. v. EPA, 696 F.2d 169 (2nd Cir. 1982); Michigan Dep't. of
Envtl. Quality v. Browner, 230 F.3d 181 (6th Cir. 2000); Mont. Sulphur
& Chem. Co. v. EPA, 2012 U.S. App. LEXIS 1056 (9th Cir. Jan. 19, 2012).
Comment: One commenter asserted that the U.S. Court of Appeals for
the D.C. Circuit's decision to vacate CSAPR is relevant to the Wyoming
FIP. EME Homer City Generation, L.P. v. EPA., 696 F.3d 7 (D.C. Cir.
2012), cert. granted 570 U.S. (June 24, 2013) (No. 12-1182) (CSPAR
Decision), and stated that EPA's proposed Wyoming FIP exceeds EPA's
statutory authority. The commenter also states that in vacating CSAPR,
the D.C. Circuit held that EPA's ``FIP-first'' approach exceeds EPA's
authority because EPA issued a FIP at the same time it determined the
emission reduction parameters that the states were supposed to
implement. The commenter stated that EPA's theory was that EPA can
define the end goals and simultaneously issue federal plans to
implement them, upending that process and placing the Federal
Government firmly in the driver's seat at both steps.
Other commenters stated that the D.C. Circuit's rejection of the
CSAPR rule is irrelevant to EPA's regional haze rulemaking for Wyoming.
They asserted that the regional haze program differs from the CAA's
good-neighbor provision in fundamental ways that make the court's
rejection of CSAPR irrelevant to EPA's action on Wyoming's regional
haze plan. The commenters stated that the CAA's visibility provisions
establish a technology-based standard for eligible major sources,
including PacifiCorp's coal-fired power plants in Wyoming. See 42
U.S.C. 7491(b)(2)(A). To help achieve ``reasonable progress'' toward
the national visibility goal, eligible sources must install BART for
haze-causing pollutants. Id. BART is defined as: ``an emission
limitation based on the degree of reduction achievable through the
application of the best system of continuous emission reduction for
each pollutant which is emitted by an existing stationary facility.''
40 CFR 51.301. The emission limitation must be established on a case-
by-case basis, taking into consideration the technology available, the
costs of compliance, the energy and non-air quality environmental
impacts of compliance, any pollution control equipment in use or in
existence at the source, the remaining useful life of the source, and
the degree of improvement in visibility which may reasonably be
anticipated to result from the use of such technology. Unlike the D.C.
Circuit's interpretation of the good-neighbor provision, the BART
definition establishes a floor for emissions reductions, but no
ceiling. States must ensure that eligible sources install the best
pollution control devices.
These commenters also argued that when a SIP fails to establish a
program that meets CAA requirements, then EPA has an obligation to
promulgate a FIP. Here, they argued, EPA carried out its statutory duty
in proposing a partial FIP for Wyoming. EPA's role is not mere
``rubber-stamping'' of poor SIPs. EPA ``has a duty to evaluate the
adequacy of the existing SIP as a whole when approving SIP revisions.''
Ass'n of Irritated Residents v. EPA, 632 F.3d 584, 591 (9th Cir. 2011).
A FIP ``fill[s] all or a portion of a gap or otherwise correct[s] all
or a portion of an inadequacy in a State implementation plan.'' 42
U.S.C.
[[Page 5054]]
7602(y) (emphasis added). In proposing to reject many of Wyoming's
inadequate BART determinations, and proposing a partial FIP, EPA is
merely acting to fulfill its own regulatory obligations under the Act.
Response: With respect to the comment that we lacked authority to
promulgate a FIP due to the D.C. Circuit's decision in EME Homer City,
we disagree. In EME Homer City, the D.C. Circuit vacated CSAPR, which
was promulgated by EPA to address interstate transport of
SO2 and NOX under CAA section 110(a)(2)(D). The
court found that CSAPR exceeded EPA's authority under section 110
because the rule had the potential to require upwind States to reduce
emissions by more than their own significant contributions to downwind
nonattainment and because EPA had not given states an opportunity to
submit SIPs after EPA had quantified their obligations for emissions
reductions.
In the regional haze context, by contrast, EPA defined states'
obligations under the RHR and the BART Guidelines well in advance of
its findings of failure to submit and subsequent SIP disapprovals. EPA
promulgated the original RHR on July 1, 1999 (64 FR 35714). Following
the D.C. Circuit's decision in American Corn Growers, EPA revised the
RHR and issued the final BART Guidelines on July 6, 2005. (70 FR
39104). The revised RHR and the BART Guidelines were upheld by the D.C.
Circuit in Utility Air Regulatory Group v. EPA, 471 F.3d 1333 (D.C.
Cir. 2006).\18\ As explained in our proposal and elsewhere in this
document, the BART Guidelines provide detailed instructions to states
on how to determine which sources are subject to BART and how to
analyze the five statutory factors in order to set emissions limits
representing BART for each subject-to-BART source.\19\ In 2006,
responding to specific questions from various states and Regional
Planning Organizations (RPOs), EPA issued further guidance to help
states implement the RHR and BART Guidelines.\20\
---------------------------------------------------------------------------
\18\ In response to another D.C. Circuit decision, Center for
Energy and Economic Development v. EPA, 398 F.3d 653 (D.C. Cir.
2005), EPA revised the RHR's provisions governing alternatives to
source-specific BART determinations on October 13, 2006. These
revisions did not alter the requirements for source-specific BART
determinations that apply to Wyoming's BART determinations at issue
here.
\19\ 40 CFR Part 51, Appendix Y. While the Guidelines are only
mandatory for fossil fuel-fired electric generating plants with a
total generating capacity in excess of 750 megawatts, States are
encouraged to follow the BART Guidelines in making BART
determinations for other types of sources. Id. section I.H. The
Guidelines also set specific presumptive limits for SO2
and NOX for these large power plants, but allow states to
apply more or less stringent limits based upon source-specific five-
factor analyses. 70 FR 39131-39132.
\20\ Memo from Joseph W. Paise Regarding Regional Haze
Regulations and Guidelines for BART (July 19, 2006); Additional
Regional Haze Questions (Guidance) (Sept. 27, 2006). In addition,
EPA issued final ``Guidance for Setting Reasonable Progress Goals
Under the Regional Haze Program'' on June 1, 2007, but this Guidance
is not directly relevant for individual BART determinations.
---------------------------------------------------------------------------
As noted in prior responses, EPA issued a finding of failure to
submit for regional haze SIPs on January 15, 2009 (74 FR 2392),
triggering a FIP clock under CAA section 110(c). By this time, states
already had more than three years since issuance of the final BART
Guidelines to develop their regional haze SIPs. By the time the FIP
clock actually ran out in January 2011, EPA had received regional haze
SIPs from nearly every state. EPA has since proposed and approved, in
part or in whole, the vast majority of these SIPs.21 22 This
stands in contrast to the situation in EME Homer City, where the court
noted that, ``every Transport Rule State that submitted a good neighbor
SIP for the 2006 24-hour PM2.5 NAAQS was disapproved.''
Thus, it is clear that states had ample opportunity to submit
approvable regional haze SIPs before EPA was obligated to promulgate
regional haze FIPs under CAA section 110(c).
---------------------------------------------------------------------------
\21\ See, e.g., 76 FR 36450 (Nevada); 77 FR 24794 (New York); 76
FR 13944 (California); 77 FR 11798 (Rhode Island); 76 FR 27973
(Delaware); 77 FR 12770 (Nebraska); 77 FR 18052 (Colorado); 76 FR
16168 (Oklahoma); 77 FR 11914 (Vermont); 77 FR 11928 (Wisconsin); 76
FR 52604 (Kansas); 76 FR 64186 (Arkansas); 77 FR 11839 (Maryland);
76 FR 58570 (North Dakota); 77 FR 3966 (Illinois); 76 FR 76646
(South Dakota). EPA proposed limited approval and limited
disapproval of the Regional Haze SIPs of states covered by the Clean
Air Interstate Rule (CAIR), due to the remand of CAIR by the D.C.
Circuit. See, e.g. 77 FR 3691 (Jan. 25, 2012) (proposing limited
approval and limited disapproval of Virginia's Regional Haze SIP).
\22\ See, e.g., 76 FR 34608 (California); 76 FR 42557
(Delaware); 76 FR 80754 (Kansas); 77 FR 19 (New Jersey); 77 FR 5191
(District of Columbia); 77 FR 14604 (Arkansas); 77 FR 17334
(Nevada); 77 FR 24845 (South Dakota); 77 FR 40150 (Nebraska); 77 FR
51915 (New York).
---------------------------------------------------------------------------
One commenter also pointed to the D.C. Circuit's general statements
concerning state and federal roles under the CAA and argues that EPA
has exceeded its statutorily mandated role in proposing to disapprove
portions of Wyoming's regional haze SIP and promulgate a FIP. While we
agree that the general principles concerning state and federal roles
under Title I of the CAA apply to our action here, we do not agree that
our action is inconsistent with those principles. In this action, we
are fulfilling our statutory duty to review Wyoming's regional haze
SIP, including its BART determinations, for compliance with the
applicable requirements of the CAA and the RHR, and to disapprove any
portions of the plan that do not meet those requirements. Based on our
review of the SIP, we proposed to determine that certain elements of
Wyoming's regional haze SIP did meet the requirements of the CAA and
the RHR, and we proposed to approve those elements. However, for the
reasons explained in detail in our proposed notices and elsewhere in
this document, we have concluded that five of Wyoming's BART
determinations \23\ and four elements of the regional haze SIP \24\ did
not comply with the requirements of the CAA and the RHR. Based on these
findings, we are required to disapprove these portions of Wyoming's
regional haze SIP. As discussed in detail in several below responses,
the CAA provides EPA with the authority to review and reject an
inadequate regional haze SIP. Oklahoma v. EPA, 723 F.3d 1201, 1207
(10th Cir. 2013).
---------------------------------------------------------------------------
\23\ As presented elsewhere in this final notice and in the
docket, the five NOX BART determinations we are
disapproving are for the following: PacifiCorp Dave Johnston Unit 3,
PacifiCorp Wyodak Unit 1, and Basin Electric Laramie River Units 1,
2, and 3.
\24\ As presented elsewhere in this final notice and in the
docket, the four elements of the State SIP we are disapproving
include: (1) Wyoming's RPGs; (2) The State's monitoring,
recordkeeping, and reporting requirements in Chapter 6.4 of the SIP;
(3) portions of the State's long term strategy (LTS) that rely on or
reflect other aspects of the regional haze SIP that we are
disapproving; and (4) the provisions necessary to meet the
requirements for the coordination of the review of the reasonably
attributable visibility impairment (RAVI) and the regional haze LTS.
---------------------------------------------------------------------------
Comment: One commenter stated that the limits on EPA's authority to
reject a SIP were affirmed by the Fifth Circuit in Texas v. EPA, 690
F.3d 670 (5th Cir. 2012), vacating EPA's rejection of a Texas SIP
revision implementing its minor new source review program (i.e., the
Texas Flexible Permit Program). In the Texas decision, the court
reaffirmed the principle that if a SIP or SIP revision meets the
statutory criteria of the CAA, then EPA must approve it. The Wyoming
regional haze SIP meets the statutory criteria of the CAA. Therefore,
EPA's disapproval of the Wyoming regional haze SIP exceeds EPA's
statutory authority.
Response: In Texas, the Fifth Circuit found that EPA had failed to
tie its disapproval to any specific requirement in the CAA or EPA's
implementing regulations.\25\ In this action, our disapproval is based
explicitly and squarely on the SIP's failure to comply with the CAA
section 169A(b)(2)(A), as implemented through the RHR and the
[[Page 5055]]
BART Guidelines. Just because a court found EPA's disapproval invalid
in one case does not mean that finding applies in all cases. This
situation involves a very different program under the CAA and a very
different state submittal and review. The Texas case does not involve
BART or the CAA's regional haze provisions at all. Rather, it involved
EPA's disapproval of SIP revisions involving Texas's minor new source
review program. There are a limited number of specific requirements in
EPA rules for minor source review programs. In contrast, regional haze
SIPs and BART determinations are subject to the detailed requirements
set forth in CAA section 169A, the RHR, and the BART Guidelines.
---------------------------------------------------------------------------
\25\ 690 F.3d at 679, 682, 686.
---------------------------------------------------------------------------
Comment: One commenter stated that the CSAPR decision criticized
the CSAPR's FIP-first approach because it forces states to ``take a
stab in the dark'' on their compliance obligations only to be judged
later whether they hit the mark. As the D.C. Circuit explained in the
CSAPR decision, a ``SIP logically cannot be deemed to lack a required
submission or deemed to be deficient for failure to meet . . . [an]
obligation before EPA quantifies the . . . obligation.'' EME Homer City
Generation, L.P. v. EPA., 696 F.3d 7, 49 (D.C. Cir. 2012), cert.
granted 570 U.S. (June 24, 2013) (No. 12-1182) (hereinafter ``CSPAR
Decision'').
Other commenters reject this assertion, explaining that Wyoming was
not forced to take a ``stab in the dark'' in developing its regional
haze SIP. In EME Homer City, the D.C. Circuit accepted the state
petitioners' argument that they had no obligation to submit SIPs until
after EPA defined each state`s contribution to interstate pollution and
the necessary emissions reductions to address that contribution. EME
Homer City, 2012 WL 3570721, at *18 (``[L]ogically, a SIP cannot be
deemed to lack a required submission . . . until after EPA has defined
the State`s good neighbor obligation.''; ``There is no way for an
upwind State to know its obligation . . . until EPA defines it.'').
Response: We do not agree that Wyoming was forced to take a ``stab
in the dark'' in developing its regional haze SIP. The regional haze
program and the interstate transport obligations under the CAA are
quite different. The states' regional haze obligations have been
clearly defined. EPA issued BART Guidelines establishing detailed
parameters for state BART determinations in 2005. Commenter's charge
that EPA may never issue a FIP in such circumstances is incorrect. We
explain in detail above how the CAA's visibility provisions and EPA's
implementing regulations differ from the good-neighbor provision at
issue in EME Homer City. Wyoming was well aware of these requirements
as it developed its regional haze SIP, through EPA comment letters and
meetings between EPA and the State. Finally, unlike the petitioners in
EME Homer City, none of the commenters here dispute that Wyoming's
regional haze SIP and BART determinations were ``required
submission[s].''
Comment: One commenter stated that the CSAPR decision also made
clear that any FIP issued by EPA must be related to the ``end goal of
the statute.'' The D.C. Circuit stated in the CSAPR decision: ``[T]he
end goal of the statute is attainment in the downwind state. EPA's
authority to force reductions on upwind states ends at the point where
the affected downwind State achieves attainment.'' CSAPR Decision at p.
25.
The ``end goal'' of the regional haze statutory requirements is to
gradually achieve ``natural visibility'' conditions by the year 2064
under an emission reduction approach known as reasonable progress as
determined by the states. EPA's rush in the proposed Wyoming FIP to
front-load as many emission reductions as possible in the first five
years of this decades-long program is a clear indication that EPA has
lost sight of the ``end goal'' of the regional haze program. Likewise,
EPA's failure to account for, and properly address, other causes of
visibility impairment in its FIP, such as natural causes (forest
fires), out of state sources, oil and gas sources, etc., demonstrates
that EPA has lost focus on the ``end goal'' of the regional haze
program. EPA's proposed Wyoming FIP violates this ``end goal''
principle espoused by the CSAPR decision.
Response: EPA is required to evaluate BART factors included in
state SIPs (e.g., ultimately rejecting methodological flaws and data
flaws in estimating costs of compliance and visibility, as we have done
in this final action), where the flaws in the analysis prevented the
State of Wyoming from conducting meaningful consideration of the BART
factors, as required by the BART Guidelines, and moored to the CAA's
BART and SIP provisions. North Dakota v. EPA, 730 F.3d 750, 761 (8th
Cir. 2013).
Furthermore, we do not agree that one provision of the CAA should
be read and applied in isolation. The commenter's position would ignore
the rest of the CAA's statutory requirements and violate the
``fundamental canon of statutory construction that the words of a
statute must be read in their context and with a view to their place in
the overall statutory scheme.'' A court must therefore interpret the
statute ``as a symmetrical and coherent regulatory scheme,'' and ``fit,
if possible, all parts into an harmonious whole.'' FDA v. Brown &
Williamson Tobacco Corp., 529 U.S. 120, 133 (2000) (quoting Davis v.
Michigan Depart of Treasury, 489 U.S. 803, 809 (1989); Gustafson v.
Alloyd Co., 513 U.S. 561, 569 (1995); and FTC v. Mandel Brothers, Inc.,
359 U.S. 385, 389 (1959)). The commenter's claim that one provision in
the CAA overrides all other statutory provisions is unfounded and not
supported by the CAA. In particular, the statutory requirements for
BART are separate and distinct from the statutory requirements for
reasonable progress.
Moreover, as explained elsewhere in this document, EPA's action
fully accounts for other causes of visibility impairment. With respect
to wildfires, we explain in detail elsewhere in this document the role
that fires play in determining natural background conditions. With
respect to oil and gas sources, we are approving the State's
determination to not impose controls on this source category during
this planning period, in part because the State already applies minor
source BACT to many of them through the State's SIP-approved minor NSR
program, and in part because controls on these sources are not so cost-
effective that we are prepared to say the State was unreasonable. With
respect to accounting for out-of-state sources, we cited sources
outside the Western Regional Air Partnership (WRAP) domain as one
factor that made it reasonable for our RPGs to fall short of the
uniform rate of progress (URP) and unreasonable to achieve the URP.
Finally, we note that we are approving some of Wyoming's BART
determinations and all of Wyoming's reasonable progress determinations.
Additionally, BART is required in the first planning period, which ends
in 2018, and is required to be installed as expeditiously as
practicable, but in no event later than five years after the effective
date of this final notice. In light of the fact that many of Wyoming's
Class I areas are not even expected to meet the URP this planning
period, the notion that EPA has required ``front-loading'' of controls
is utterly without merit.
Comment: Some commenters stated that the CSAPR decision considered,
and then rejected, a ``reasonableness'' standard put forth by EPA as
the only limit on its authority to impose emission reductions under the
CSAPR. CSAPR Decision at p. 37, ftnt. 23. EPA likewise purports to
impose a
[[Page 5056]]
reasonableness standard as adequate justification for rejecting the
Wyoming regional haze SIP and imposing a FIP. The CSAPR decision makes
clear that such a reasonableness standard, not included in the CAA
itself, does not have a place in justifying EPA's actions in issuing a
FIP. For this added reason, the CSAPR decision makes clear the FIP
exceeds EPA's statutory authority.
Response: EPA disagrees with this comment. First, the commenters
misunderstand the cited footnote in the CSAPR decision. In the D.C.
Circuit's view, EPA ignored statutory limits on its authority and
instead claimed that reasonableness was the only bound on EPA's
authority. Here, EPA makes no such claim. EPA, of course, has the
authority and the duty to review Wyoming's SIP for compliance with the
CAA and the RHR.
In reviewing the Wyoming regional haze SIP, EPA has determined that
a ``reasonableness'' standard is in fact harmonious with the CAA and
the RHR, and the courts have agreed. Oklahoma v. EPA, 723 F.3d 1201,
1207 (10th Cir. 2013) (``The EPA therefore had a reasonable basis for
rejecting the 2008 Cost Estimates [that were based on the overnight
costing method] as not complying with the guidelines.''); see also
North Dakota v. EPA, 730 F.3d 750, 761 (8th Cir. 2013) (explaining EPA
is not required to ``approve a BART determination that is based upon an
analysis that is neither reasoned nor moored to the CAA's
provisions'').
The CAA requires states to submit SIPs that contain such measures
as may be necessary to make reasonable progress toward achieving
natural visibility conditions, including BART. The CAA accordingly
requires the states to submit a regional haze SIP that includes BART as
one necessary measure for achieving natural visibility conditions. See
Alaska Dep't of Envtl. Conservation v. EPA, 540 U.S. 461, 500 (2004)
(in a related context, holding that EPA validly issued stop work orders
because the state's BACT determination ``simply did not qualify as
reasonable in light of the statutory guides.'' (emphasis added))
(hereinafter ``ADEC''). Thus we are not establishing a new
reasonableness standard, as the commenter asserts.
Comment: In the CSPAR decision, the D.C. Circuit found it
``inconceivable'' that Congress would bury in the CAA ``an open-ended
authorization for EPA to effectively force every power plant in the
upwind States to install every emissions control technology EPA deems
`cost effective'.'' CSAPR Decision at p. 40. In so finding, the court
refused to transform a ``narrow'' provision into a ``broad and
unusual'' authority that would overtake other core provisions of the
Act.'' Id. Similarly, it is inconceivable in the regional haze context
that Congress would bury an open-ended authorization allowing EPA to
ignore its own BART Guidelines, overrun carefully crafted state
regional haze SIPs and BART determinations, and require the
installation of expensive emission controls which result in minimal
regional haze improvements. This principle espoused in the CSAPR
decision is particularly applicable in the regional haze context where,
just like in the CSAPR, EPA's BART determinations in the Wyoming FIP
are ``not a clear numerical target--far from it--until EPA defines the
target.'' CSAPR Decision at p. 48. And in spite of EPA initially
helping to define ``the target'' by issuing its BART Guidelines (which
EPA subsequently ignored), EPA did not begin to redefine the target
until it began to issue various determinations around the country in
reaction to various state regional haze SIPs. Even then, EPA's
``target'' is not clear and certainly is impossible to determine, on a
state or source-by-source basis, until EPA sets the target in a state-
specific FIP.
Like the upwind states in the CSAPR decision, it was ``impossible''
for Wyoming to determine its regional haze obligation ``until EPA
defined it.'' Id. This process effectively allows EPA to impose any
standard it wants with little ability for the states (or sources) to
achieve the redefined target through a state-led process because of the
tight deadlines imposed by EPA as a result of negotiated consent decree
deadlines.
Response: We do not agree that we have ignored the CAA and BART
Guidelines. As explained in our proposed notice and elsewhere in this
document, our decisions are firmly grounded on the CAA provisions and
BART Guidelines, and Wyoming was well aware of these requirements as it
developed its SIP. In addition, the comparison of BART determinations
and the CSAPR decision is not appropriate. In contrast to CSPAR, the
CAA and RHR do not set specific numerical targets for BART
determinations. Instead, they require states to reasonably consider the
five statutory factors, which, as we have detailed in our proposal and
in our response to comments, Wyoming did not do. Furthermore, EPA
provided extensive comments to the State on the proposed regional haze
SIP and met with the State on numerous occasions, so the State was
aware of EPA's concerns regarding approvability before the SIP was
submitted to EPA. As explained below in greater detail, the Consent
Decree that covers this action has not hindered Wyoming's ability to
develop and submit an approvable SIP. Wyoming can submit new SIP
revisions, and request that EPA review and approve them, to replace the
FIP elements at any time.
To the extent that the comment argues that the RHR itself is
invalid for similar reasons to those for which the D.C. Circuit vacated
CSAPR, the time to make those arguments has passed.
Finally, in establishing the BART requirements, Congress was
addressing a category of large sources that pre-dated the modern NSR
affected sources, which were determined to significantly contribute to
regional haze and set an expectation that included consideration of
cost, feasibility, and effect on regional haze (as well as the other
five factors) for those sources, many of which did not have modern
pollution controls because of their age and because they hadn't been
addressed through ozone SIPs the way so many eastern sources had. This
is one of the reasons why the western regional haze SIPs are seeing
emission controls.
Comment: One of the commenters stated that one of the key
conclusions of the CSAPR decision was that EPA exceeded the scope of
its authority by requiring emission reductions beyond the statutory or
regulatory requirements. In the CSAPR decision, the court looked at the
fact that once EPA had determined that an upwind emission source
contributed ``significantly'' to nonattainment or maintenance of the
standard in a downwind state; it was ``in'' for purposes of requiring
emission reductions. The emission reduction requirements were then
based on cost-effectiveness thresholds that were applied uniformly
throughout the CSAPR region. In other words, all emissions that could
be reduced, for example, for a cost between $1 and $500 per ton were
effectively required. The court held that this approach resulted in a
situation where some sources had to bear a disproportionate amount of
costs, based on their relative contribution to the nonattainment or
maintenance problem.
Similarly in the regional haze context, EPA established an ``in or
out'' criteria of a 0.5 deciview impact. Sources with modeling results
that suggested the impact was greater than 0.5 were ``in'' and required
further analysis. If, under EPA's FIP approach, the facilities could
cost-effectively (as determined by EPA, not the states) control
emissions, they were required to do so. Oftentimes, EPA has required
the controls notwithstanding the negligible contribution the emission
reductions
[[Page 5057]]
will have towards meeting the requirement of the RHR. EPA's conclusions
requiring individual sources to reduce emissions under its subjective
cost-effectiveness criteria have no relationship to visibility impacts
or improvements, and EPA failing to conduct that modeling, but
supporting a determination of reasonableness of controls ``based on the
high cost effectiveness at each of the units.'' 77 FR at 33034, 33038
and 33055.
EPA's conclusions regarding emission reductions that are based on
the cost-effectiveness of controls without an appropriate linkage to
visibility improvement and meeting the goals and objectives of the RHR
exceed EPA's statutory authority as suggested by the CSAPR decision.
Response: We agree with some of this comment and disagree with
other portions. As an initial matter, as we explained in our proposed
notice, we note that:
Wyoming used a contribution threshold of 0.5 deciviews for
determining which sources are subject-to-BART. By using a
contribution threshold of 0.5 deciviews, Wyoming exempted seven of
the fourteen BART-eligible sources in the State from further review
under the BART requirements. Based on the modeling results, the
State determined that P4 Production, FMC Granger, and OCI Wyoming
had an impact of .07 deciview, 0.39 deciview, and 0.07 deciview,
respectively, at Bridger Wilderness. Black Hills Neil Simpson 1,
Sinclair Casper Refinery, and Sinclair--Sinclair Refinery have an
impact of 0.27 deciview, 0.06 deciview, and 0.12 deciview,
respectively, at Wind Cave. Dyno-Nobel had an impact of 0.22
deciview at Rocky Mountain National Park. These sources' modeled
visibility impacts fell below the State's threshold of 0.5 deciview
and were determined not to be subject-to-BART. 78 FR 34747
Since the State's approach is consistent with the BART Guidelines \26\
and given the relatively limited impact on visibility from these seven
sources, as explained earlier in this document and in our proposals, we
are finalizing our proposal to approve Wyoming's threshold of 0.5
deciviews as reasonable for determining whether its BART-eligible
sources are subject-to-BART. 78 FR 34734, 34747
---------------------------------------------------------------------------
\26\ 40 CFR part 51, appendix Y, section III.A.1.
---------------------------------------------------------------------------
We do not agree that our decision exceeds our statutory authority
and the goals and objectives of the RHR. CAA section 110(a)(2)(J)
requires each plan submitted by a state to ``meet the applicable
requirements'' of Part C of Title I of the CAA, including those for
``visibility protection.'' In the case of a regional haze SIP
submittal, the ``applicable requirements'' include the requirement that
each source found subject-to-BART, ``procure, install, and operate, as
expeditiously as practicable (and maintain thereafter) the best
available retrofit technology . . .'' \27\ Section 169A(g)(2) further
provides that:
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\27\ CAA section 169A(b)(2)(A), 42 U.S.C. 7491(b)(2)(A).
In determining best available retrofit technology the State (or
the Administrator in determining emission limitations which reflect
such technology) shall take into consideration the costs of
compliance, the energy and non-air quality environmental impacts of
compliance, any existing pollution control technology in use at the
source, the remaining useful life of the source, and the degree of
improvement in visibility which may reasonably be anticipated to
result from the use of such technology.\28\
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\28\ 42 U.S.C. 7491(g)(2).
---------------------------------------------------------------------------
Similarly, the RHR provides that:
The determination of BART must be based on an analysis of the
best system of continuous emission control technology available and
associated emission reductions achievable for each BART-eligible
source that is subject to BART within the State. In this analysis,
the State must take into consideration the technology available, the
costs of compliance, the energy and non-air quality environmental
impacts of compliance, any pollution control equipment in use at the
source, the remaining useful life of the source, and the degree of
improvement in visibility which may reasonably be anticipated to
result from the use of such technology.\29\
---------------------------------------------------------------------------
\29\ 40 CFR 51.308(e)(1)(ii)(A).
Wyoming's BART determinations for NOX at five BART units
fall short of these requirements in several respects.
First, Wyoming did not analyze the ``best system of continuous
emission control technology available and associated emission
reductions achievable.'' This is explained in detail in our proposed
rulemaking, the docket for this action, and elsewhere in this document.
Therefore, Wyoming has not demonstrated that its BART determinations
were ``based on an analysis of the best system of continuous emission
control technology available and associated emission reductions
achievable.''
For example, as we explained in our proposed notices and elsewhere
in this final action, Wyoming did not appropriately consider the
``degree of improvement in visibility which may reasonably be
anticipated'' from installation of BART because it did not provide
visibility improvement modeling from which the benefits of individual
NOX controls could be ascertained. Thus Wyoming's BART
determinations for NOX do not meet the requirements of CAA
section 169A(g)(2) or 40 CFR 51.308(e)(1)(ii)(A).
Additionally, as explained in our proposed notices and elsewhere in
the modeling section of this final action, it was not possible to
ascertain the visibility improvement from the NOX control
options as the State modeled emission reductions for multiple
pollutants together. For this reason, in the modeling conducted by EPA,
we held SO2 and PM emission rates constant (reflecting the
``committed controls'' for those pollutants identified by Wyoming), and
varied only the NOX emission rate. This allowed us to
isolate the degree of visibility improvement attributable to the
NOX control option.
In addition, 40 CFR 51.308(e)(1)(ii)(B) provides that the
determination of BART for fossil-fuel fired power plants having a total
generating capacity greater than 750 megawatts must be made pursuant to
the guidelines in appendix Y of part 51 (Guidelines for BART
Determinations under the Regional Haze Rule).
All of the Wyoming BART sources, except Wyodak, each have a
generating capacity greater than 750 megawatts. Therefore, the BART
determinations for these BART sources must be made pursuant to the BART
Guidelines. However, Wyoming's BART determinations for these sources
did not fully comply with the BART Guidelines. In particular, as
explained more fully elsewhere in this document, contrary to the
Guidelines' admonition that ``cost estimates should be based on the
CCM, where possible,'' the control cost calculations supplied by the
utilities and relied upon by Wyoming included costs not allowed by the
CCM, such as owner's costs and Allowance for Funds Utilized During
Construction (AFUDC). Thus, Wyoming's consideration of the ``cost of
compliance'' for these units was not consistent with the Guidelines.
Furthermore, as explained elsewhere in this document, Wyoming's
consideration of visibility benefits was inconsistent with the
Guidelines because the State did not provide visibility modeling from
which the visibility improvement from individual controls could be
ascertained. Finally, for all pollutants at all units covered by
today's action, Wyoming's regional haze SIP does not meet the
requirements of 40 CFR 51.308(e)(1)(iv) and (v) because it lacks the
following elements:
A requirement that each source subject to BART be required
to install and operate BART as expeditiously as practicable, but in no
event later than 5 years after approval of the implementation plan
revision.
[[Page 5058]]
A requirement that each source subject to BART maintain
the control equipment required by this subpart and establish procedures
to ensure such equipment is properly operated and maintained.
These two requirements are mandatory elements of the RHR and are
necessary to ensure that BART is procured, installed, and operated as
expeditiously as practicable and maintained thereafter, as required
under CAA section 169A(b)(2)(A).
Moreover, the CAA and regional haze rule require that SIPs contain
provisions that make emissions limits, including BART limits,
practically enforceable. CAA section 110(a)(2)(A)-(B) require that
emissions limits such as BART be ``practically enforceable'' and SIPs
provide for establishment, methods and procedures necessary to monitor,
compile, and analyze data. CAA section 302(k) requires emissions limits
to be met on a continuous basis. Additionally, CAA section 169A(b)(2)
requires that regional haze SIPs include ``such emission limits,
schedules of compliance and other reasonable measures'' necessary to
meet the goals of the regional haze program.'' As discussed in our
proposed notices and elsewhere in this final notice, Wyoming's regional
haze SIP lacks requirements for monitoring, recordkeeping, and
reporting sufficient to ensure that the BART limits are enforceable and
are met on a continuous basis.
Therefore, Wyoming's BART determinations for these five units
covered by the FIP do not meet the BART requirements of the CAA, the
RHR and the BART Guidelines. Additionally, Wyoming's SIP requirements
do not ensure the BART limits are enforceable for all BART sources for
which there is a SIP or FIP emissions limit, and therefore do not meet
the requirements of the CAA and RHR. Accordingly, we are compelled to
partially approve and partially disapprove Wyoming's regional haze SIP.
Comment: EPA cannot invoke its Section 110 SIP approval authority
as grounds for rejecting state BART determinations with which it
disagrees. The CAA does not require any specific degree of visibility
improvement in the determination and only requires BART for the purpose
of eliminating or reducing impairment to visibility. See CAA Section
169A, 42 U.S.C. 7491.
Consistent with the long-recognized principle that EPA may not
``condition approval of the plan of any State, on the State's adoption
of a specific control measure,'' Virginia, 108 F.3d at 1408, EPA has no
statutory authority to disapprove a SIP that contains a BART
determination for an individual facility that complies with the
statutory BART factors. Any other result would allow EPA to employ its
generalized SIP approval authority to ``run roughshod over the
procedural prerogatives that the Act has reserved to the States.''
Bethlehem Steel Corp., 742 F.2d at 1036.
The fact that states must propose SIP revisions ``as may be
necessary'' to achieve reasonable progress does not mean EPA has
authority to countermand the textual commitment of specific BART
decisions to the states. The D.C. Circuit interpreted similar language
in Section 110(k)(5) to constrain EPA's authority over SIP approval and
disapproval. See Virginia, 108 F.3d at 1409. The SIP call provisions of
Section 110(k)(5) state that when a SIP is inadequate ``the
Administrator shall require the State to revise the plan as necessary
to correct such inadequacies.'' But the Virginia court rejected the
agency's expansive view of this phrase as authority to impose specific
control measures for specific emission sources.
Response: States are required by the CAA to address the BART
requirements in their SIP. Our disapproval of the NOX BART
determinations in the Wyoming regional haze SIP is authorized under the
CAA because the State's NOX BART determinations for the five
units do not satisfy the statutory criteria. The State's analysis of
the cost effectiveness of controls and visibility analyses were flawed
due to reasons discussed elsewhere in the proposed and final notices.
While states have authority to exercise different choices in
determining BART, the determinations must be reasonably supported.
Wyoming's errors in taking into consideration the costs of compliance
were significant enough that we cannot conclude the State determined
BART according to CAA standards. The cases cited by the commenters
stress important limits on EPA authority in reviewing SIP submissions,
but our disapproval of these NOX BART determinations for the
five units has an appropriate basis in our CAA authority. We did not
require Wyoming to adopt specific control measures for specific
emission sources. Instead, we disapproved some of Wyoming's BART
determinations for reasons described in detail in our proposal and
elsewhere in our response to comments. To promulgate our FIP, EPA then
had both the authority and the duty to determine specific control
measures for specific sources.
Finally, contrary to the commenter's assertion, the Bethlehem Steel
case is inapplicable here. We are promulgating BART emission
limitations and other FIP elements described elsewhere in this document
under the authority of CAA section 110(c), not through our action on
Wyoming's SIP. We have authority to promulgate our FIP under 110(c) on
two separate grounds: first, based on our January 2009 finding of
failure to submit the regional haze plan elements required by 40 CFR
51.309(g), the reasonable progress requirements for areas other than
the 16 Class I areas covered by the Grand Canyon Visibility Transport
Commission Report; and second, based on our partial disapproval of the
regional haze SIP.
Comment: We received comments that EPA does not have the authority
under the CAA to issue a regional haze FIP in this instance. Commenters
contend that EPA's role under Section 110 in reviewing states' regional
haze SIPs is narrow and that the CAA confines EPA to the ministerial
function of reviewing SIPs for consistency with the CAA's requirements.
Commenters assert that Wyoming submitted a regional haze SIP that met
the requirements of Section 51.309 and included all the required
elements and that EPA admits that Wyoming has considered all five BART
factors. Therefore, commenters go on to say that EPA's sole function
was to review whether Wyoming followed the regional haze requirements,
including Appendix Y, in preparing the Wyoming regional haze SIP, and
Congress did not authorize EPA to ``second guess'' Wyoming's BART
decision making, or to substitute its own judgment, simply because EPA
would prefer different BART and reasonable progress NOX
controls. Commenters go on to point out that courts have consistently
held that states are primarily responsible for SIP development; EPA's
role is ministerial. Commenters cite that the Supreme Court has
recognized the states' primary role in developing SIPs, holding ``so
long as the ultimate effect of a State's choice of emission limitations
is in compliance with the national standards for ambient air, the State
is at liberty to adopt whatever mix of emission limitations it deems
best suited to its particular situation.'' Train v. NRDC, 421 U.S. 60,
79 (1975). Commenters argue that EPA is going beyond its ministerial
function of reviewing Wyoming's regional haze SIP for consistency with
the CAA's requirements; it is attempting to design Wyoming's SIP by
establishing new NOX emission limits, contrary to its
promulgated BART regulations. Commenters go on to say that EPA
[[Page 5059]]
should follow the structure of the CAA and give deference to the
State's judgment in determining BART in Wyoming's regional haze SIP.
Response: States are required by the CAA to address the BART
requirements in their SIP. Our disapproval of the NOX BART
determinations in the Wyoming regional haze SIP is authorized under the
CAA because the State's NOX BART determinations for the five
units do not satisfy the statutory criteria. The State's analyses of
the cost effectiveness of controls and visibility analyses were flawed
due to reasons discussed in the introduction and BART sections of this
document. While states have the authority to exercise different choices
in determining BART, the determinations must be reasonably supported.
Wyoming's errors in taking into consideration the costs of compliance
and visibility analyses were significant enough that we cannot conclude
the State determined BART according to CAA standards. The cases cited
by the commenters stress important limits on EPA authority in reviewing
SIP submissions, but our disapproval of these NOX BART
determinations for the five units has an appropriate basis in our CAA
authority.
Comment: Under the CAA, both the federal government and the states
have responsibilities for maintaining and improving air quality. The
federal government has the authority to set specific emissions targets,
but the states have the authority to develop and impose their own
regulatory structure to meet those. As long as the State meets its
specific criteria, which Wyoming can and will show that it has done,
the fact that EPA does not share the State's opinion regarding the best
course of action is immaterial.
This reading of the CAA is the opinion of the Congress that passed
the regional haze program in 1977. Committee and floor debate in
Congress at the time makes clear that Congress fully intended for the
states to possess a high degree of primacy in regional haze decisions.
The primary sponsor of the CAA and 1977 amendments in the Senate was
the late Senator Edmund Muskie, a Democrat from Maine. In his opening
address to the Senate on the Conference Report to the 1977 amendments,
Senator Muskie said, ``under this legislation, the administrator of the
EPA will be more reliant on local and state capabilities to create the
institutional and infrastructural changes necessary to achieve clean
air. And perhaps this is as it should be. We have learned that there is
little political support for inartfully conceived national measures. We
have learned that where change can be made, it must be made with the
full understanding and support of the people who are affected by that
change.''
While the courts in some instances may not give adequate weight to
the intent of Congress in drafting legislation, Congress's intent in
passing the nation's law is something that Congress itself takes very
seriously. Some courts have honored Congressional intent and upheld the
CAA as a cooperative statute. In Appalachia Power Company v. EPA [sic],
the courts determined that the CAA includes a cooperative standard they
call a federalism bar. In Train and Luminant Generation Co., LLC v.
EPA, 675 F.3d 917 (5th Cir. 2012) (hereinafter ``Luminant''), the
courts held that the EPA had no authority to overturn the decisions of
the states so long as the basic requirements of Section 110 are met.
EPA does not have the authority under the CAA to issue a regional
haze FIP in this instance. EPA contends its review of the Wyoming SIP
is ``pursuant to section 110 of the CAA.'' 78 FR 34738. Section
110(a)(2) provides the general requirements that a SIP must contain.
Importantly, EPA's role under Section 110 in reviewing states' regional
haze SIPs is narrow: ``With regard to implementation, the (CAA)
confines the EPA to the ministerial function of reviewing SIPs for
consistency with the (CAA)'s requirements.'' Luminant Generation Co.,
LLC v. EPA, 675 F.3d 917, 921 (5th Cir. 2012) (citing section
110(k)(3)). As the court in Luminant explained, if the state's
submissions ``satisfy those basic requirements (found in section 110),
the EPA must approve them,'' and ``(t)hat is the full extent of the
EPA's authority in the SIP-approval process because that is all the
authority that the CAA confers.'' Id. at 932. Here, Wyoming submitted a
regional haze SIP that met the requirements of Section 309 and included
all the required elements. The Wyoming SIP submittals are well
developed and comprehensive. EPA admits that Wyoming considered all
five BART factors. 78 FR 34748. Therefore, EPA's role was to review
whether Wyoming followed the regional haze requirements, including
Appendix Y, and provided factual support for the Wyoming regional haze
SIP. Congress did not authorize EPA to ``second guess'' Wyoming's BART
decision making, or to substitute its own judgment, simply because EPA
would prefer different BART and reasonable progress NOX
controls.
More recently, the D.C. Court vacated the CSAPR. The court's 2012
opinion in the CSAPR case is illustrative for our purposes because the
EPA used very similar arguments to justify their authority in CSAPR as
they're using today for regional haze. In vacating the CSAPR rule, the
D.C. Circuit Court writes ``under the CAA, the federal government sets
air quality standards, but states retain the primary responsibility for
choosing how to attain those standards within their borders. The Act
thus leaves it to the individual states to determine, in the first
instance, the particular restrictions that will be imposed on
particular emitters within their borders.'' The court goes on to write
that ``. . .the statutory federalism bar prohibits the EPA from using
the SIP process to force states to adopt specific control measures.''
Response: We responded to similar comments above.\30\ With respect
to EPA's supposed admission that Wyoming considered the five BART
factors, the precise language in the proposal notice is: ``We find that
Wyoming considered all five steps above in its BART determinations, but
we propose to find that its consideration of the costs of compliance
and visibility improvement for the EGUs was inadequate and did not
properly follow the requirements in the BART Guidelines and statutory
requirements, as explained below.'' 78 FR 34748. With respect to the
legislative history quoted, the comment does not provide any connection
between the general remarks of Senator Muskie regarding the 1977
Amendments and EPA's interpretation of the visibility provisions in the
Act.
---------------------------------------------------------------------------
\30\ As the commenter mentions, we agree that we did approve
Wyoming's regional haze SIP submitted under Section 309 of the RHR
(40 CFR 51.309) (77 FR 73926 (Dec. 12, 2012)), as in that action we
determined the State met the requirements of 40 CFR 51.309 and
related provisions.
---------------------------------------------------------------------------
Comment: We received numerous general comments that EPA has
overstepped its authority and that states have the responsibility of
determining what controls are necessary for regional haze.
Response: As explained earlier, the states have the responsibility
to draft the regional haze SIP and EPA has the responsibility of
ensuring state plans, including regional haze SIPs, conform to the CAA.
As the drafter of the regional haze SIP, the State generally has the
authority to decide how each of the BART factors are taken into account
and weighed. EPA is not disapproving Wyoming's BART determinations
because we disagree with how Wyoming weighed the relevant factors, such
as the cost of controls or the degree of visibility improvement
resulting from
[[Page 5060]]
the use of controls. EPA is disapproving certain Wyoming BART
determinations because the State did not consider these factors in its
BART determinations in accordance with the RHR and the Act.
Comment: EPA's regional haze FIP failed to afford the required
deference to the technical, policy and other discretion granted to
Wyoming under the CAA and regional haze program. Congress added section
169A to the CAA in order to address the ``impairment of visibility'' in
Class I areas that ``results from man-made air pollution.'' This
provision of the CAA, in turn, describes separate roles for EPA, the
states, and major sources such as PacifiCorp's BART Units.
EPA's roles are to create a report, see CAA section 169A(a)(2)-(3),
create regional haze regulations, see CAA section 169A(a)(4), provide
guidelines for the states, see CAA section 169A(b)(1), and determine
whether regional haze SIPs submitted by the states follow the
regulations and guidelines, and contain the required elements. CAA
section 110. The states' roles, which are central to the regional haze
program, are intended to be accomplished using substantial discretion
which, in turn, requires significant deference from EPA. States are
required to submit a regional haze SIP that contains ``emission limits,
schedules of compliance and other measures as may be necessary to make
reasonable progress toward meeting the national goal.'' CAA section
169A(b)(2). States also must ``determine[*thnsp;]'' BART for ``each
major stationary source.'' CAA 169A(b)(2)(A). BART sources, such as
PacifiCorp's BART units, are required to ``procure, install, and
operate (BART) as expeditiously as practicable.'' CAA section
169A(b)(2)(A).
Thus, the CAA mandates that states have the primary role in
developing regional haze SIPs to protect visibility in Class I areas.
Likewise, the RHR makes clear that states have the responsibility to
create and implement regional haze SIPs. In contrast, EPA's role is to
develop ``guidelines'' for the states to use in implementing regional
haze SIPs and to determine whether states followed those guidelines.
CAA section 169A(b)(1). In short, the CAA anticipates that states,
using their discretion, develop regional haze SIPs using EPA
guidelines. This is exactly what Wyoming did in issuing BART permits
and developing the Wyoming regional haze SIP.
In issuing regional haze guidelines, EPA recognized the broad
discretion granted to the states by the CAA. Specifically, EPA adopted
guidance to address BART determinations for certain large electrical
generating facilities, referred to as ``Appendix Y.'' EPA created
further guidance in the Federal Register responding to comments
concerning the then-proposed Appendix Y, referred to as the
``Preamble.'' EPA recognized in the Preamble that ``how states make
BART determinations or how they determine which sources are subject to
BART'' are among the issues ``where the Act and legislative history
indicate that Congress evinced a special concern with insuring that
states would be the decision makers.'' 70 FR 39104, 39137 (July 6,
2005).
Likewise, in analyzing the applicability of certain executive
orders, EPA stated that ``ultimately states will determine the sources
subject to BART and the appropriate level of control for such sources''
and that ``states will accordingly exercise substantial intervening
discretion in implementing the final rule.'' Id. at 39155. The U.S.
Court of Appeals for the D.C. Circuit has affirmed that EPA's role
regarding regional haze programs is limited and that a state's role is
paramount. Indeed, the Court found that the CAA ``calls for states to
play the lead role in designing and implementing regional haze
programs.'' American Corn Growers Ass'n v. E.P.A., 291 F.3d 1, 2 (D.C.
Cir. 2002). The court also reversed a portion of EPA's original RHR
because it found that EPA's method of analyzing visibility improvements
distorted the statutory BART factors and was ``inconsistent with the
Act's provisions giving the states broad authority over BART
determinations.'' Id. at 8; (see also Utility Air Regulatory Group v.
EPA, 471 F.3d 1333, 1336 (D.C. Cir. 2006) (The second step in a BART
determination ``requires states to determine the particular technology
that an individual source `subject to BART' must install.'')). The
court in American Corn Growers emphasized that Congress specifically
entrusted states with making BART five-factor analysis decisions:
``[t]o treat one of the five statutory factors in such a dramatically
different fashion distorts the judgment Congress directed the states to
make for each BART-eligible source.'' American Corn Growers, 291 F.3d
at 6.
The court in American Corn Growers also outlined the relevant
legislative history that recounts a specific agreement reached in
Congress which granted this authority to the states: ``The `agreement'
to which the Conference Report refers was an agreement to reject the
House bill's provisions giving EPA the power to determine whether a
source contributes to visibility impairment and, if so, what BART
controls should be applied to that source. Pursuant to the agreement,
language was inserted to make it clear that the states--not EPA--would
make these BART determinations. The Conference Report thus confirms
that Congress intended the states to decide which sources impair
visibility and what BART controls should apply to those sources. The
RHR attempts to deprive the states of some of this statutory authority,
in contravention of the Act.'' Id. at 8. EPA's FIP action makes the
same mistake and, if finalized, will be similarly reversible.
In sum, based on the language in the CAA, the RHR, EPA's own
guidelines, and case law, the states have significant discretion when
creating regional haze SIPs.
Response: We responded to similar comments above and elsewhere in
this document.
Comment: EPA failed to properly account for that discretion in
analyzing the Wyoming regional haze SIP. EPA should have acknowledged
that the Wyoming regional haze SIP followed the law and was supported
by the facts. Examples of EPA ignoring Wyoming's discretion include:
Visibility improvement; cost effectiveness analysis; modeling;
application of the five BART factors; and reasonable progress analyses.
Response: We responded to similar comments above and elsewhere in
this document.
Comment: EPA's proposed action ignores the congressional commitment
to have local decisions under the CAA--particularly those relating to
BART--made by the states. States have the primary responsibility for
preventing air pollution under the CAA. CAA section 101(a)(3), 42
U.S.C. 7401(a)(3). Pursuant to this principle, states, not EPA, have
always had primary control over decisions to impose specific emission
limits (and therefore specific pollution control technologies) for
individual facilities. By congressional design, under the CAA EPA ``is
relegated . . . to a secondary role in the process of determining and
enforcing the specific, source-by-source emission limitations which are
necessary [to meet] national standards.'' Train v. NRDC, 421 U.S. 60,
79 (1975) (hereinafter ``Train''). This basic division of
responsibilities between EPA and the States remained unchanged when
Congress amended the Act in 1977 and again in 1990. See Virginia v.
EPA, 108 F.3d 1397, 1408-10 (D.C. Cir. 1997).
Congress took this principle a step further under the regional haze
program, specifically directing that BART is to be
[[Page 5061]]
``determined by the State.'' CAA section 169A(b)(2)(A), 42 U.S.C.
section 7491(b)(2)(A). Congress adopted the BART provisions to address
visibility, rather than health concerns. See H.R. Rep. 95-294, at 529
(1977) (``It should be made clear at the outset that this provision
[concerning BART] is totally unrelated to any question involving public
health.'') (separate views of Messrs. Devine, Krueger, Broyhill,
Gammage, Clarence J. Brown, Collins, Moore and Stockman). Congress
therefore sensibly left decisions relating to the imposition of costly
visibility control technologies on certain existing sources entirely to
the states, where local factors could be properly considered and
implemented:
The agreement clarifies that the state, rather than the
Administrator, identifies the source that impairs visibility in the
Federal class I areas. ``. . . In establishing emission limitations
for any source which impairs visibility, the State shall determine
what constitutes `best available retrofit technology' . . .'' H.R.
Conf. Rep. 95-564, at 155 (1977). While the original House bill
would have given EPA the power to determine what BART controls
should be applied to individual sources, Congress eventually
inserted the current statutory language to make it clear that the
States, rather than EPA, would make BART determinations. See id.; 5
Leg. History of CAA Amendments 1997 P.L. 95-95, H8663 (1997) (``The
provision [in the original bill] was modified to give States a
greater role in identifying sources which are contributing (or may
in the future contribute) to visibility problems and in establishing
control requirements for those sources.''). Senator Muskie confirmed
during the floor debate that ``the State, not the Administrator,
identifies a source that may impair visibility'' and that ``it is
the State which determines what constitutes `Best Available Retrofit
Technology.' '' 123 Cong. Rec. 26,854 (1977).
The federal courts have enforced this legislative intent. In
American Corn Growers, the D.C. Circuit quoted at length from the
legislative history of section 169A to conclude that it was ``clear
that the States--not EPA--would make these BART determinations.'' 291
F.3d at 8; see also id. at 8 (``The Conference Report . . . confirms
that Congress intended the States to decide which sources impair
visibility and what BART controls should apply to those sources.'').
American Corn Growers reaffirms that the states have ``broad
authority'' to make their own BART determinations. Id. It also
reaffirms that EPA cannot ``deprive the states of some of this
statutory authority,'' nor can EPA ``constrain[ ] authority Congress
conferred on the states'' with respect to BART determinations. Id. at
8-9. It was for this reason that the court struck EPA's first attempt
at the Regional Haze Rule: it purported to tell the states how to make
BART determinations. Id. at 6-7. The same court later reiterated that
BART ``requires States to determine the particular technology that an
individual source `subject to BART' must install.'' Utility Air
Regulatory Grp. v. EPA, 471 F.3d 1333, 1336 (D.C. Cir. 2006).
Other federal courts have recognized the cooperative federalism
policies on which the CAA in general--and the regional haze provisions
in particular--are based. See, e.g., Texas v. EPA, 690 F.3d 670, 684
(5th Cir. 2012); Ellis v. Gallatin Steel Co., 390 F.3d 461, 467 (6th
Cir. 2004); Sierra Club v. EPA, 315 F.3d 1295, 1300 (11th Cir. 2002);
Am. Lung Ass'n of N.J. v. Kean, 871 F.2d 319, 322 (3d Cir. 1989). Under
cooperative federalism, states retain the discretion and flexibility to
make their own choices based on local conditions, histories, and
policies. See, e.g., Budget Prepay, Inc. v. AT&T Corp., 605 F.3d 273,
281 (5th Cir. 2010) (`` `cooperative federalism' . . . necessarily
implies that states may reach differing conclusions on specific issues
relating to the implementation of the [statute]''); Global NAPs, Inc.
v. Mass. Dep't of Telecom. & Energy, 427 F.3d 34, 46 (1st Cir. 2005)
(cooperative federalism has ``the intended effect of leaving state
commissions free, where warranted, to reflect the policy choices made
by their states'' and to implement statutory provisions ``fairly and
with due regard to . . . local conditions . . . and . . . historical
circumstances''); Taylor v. Vt. Dep't of Educ., 313 F.3d 768, 777 (2d
Cir. 2002) (```[c]ooperative federalism . . . allows some substantive
differentiation among the states in the determination of which . . .
theories, practices, and approaches will be utilized''') (citation
omitted).
In sum, Congress directed that BART determinations are to be made
by the states, allowing the states to make their own BART choices based
on local conditions and other considerations. Because EPA may not
exercise authority ``in a manner that is inconsistent with the
administrative structure that Congress enacted into law,'' ETSI
Pipeline Project v. Missouri, 484 U.S. 495, 517 (1998), EPA may not
disapprove a state BART determination that complies with the CAA,
whether or not EPA agrees with the state's decision. Here, EPA has not
demonstrated that Wyoming's BART determination violates the CAA, and
for that reason EPA must approve the BART determination in the SIP even
if it ``disagrees'' with it. Instead, just as in its rulemaking at
issue in Texas, EPA's Proposed Rule ``transgresses the CAA's delineated
boundaries of [the] cooperative relationship'' between EPA and the
states. 690 F.3d at 686. Response: EPA disagrees with this comment.
First, the legislative history of the 1977 Amendments cited by the
commenter is incomplete. The complete legislative history, when fairly
read, contradicts the commenter and confirms EPA's supervisory role in
reviewing state regional haze SIP submittals, including the state's
initial BART determinations.
The 1977 Amendments resulted from a conference agreement that
reconciled the House bill, H.R. 6161, and the Senate bill, S. 252. The
conference committee agreed to adopt the visibility protection
provisions of section 116 of the House bill, with certain
modifications. With respect to the BART provision in what is now
section 169A(b)(2)(A) of the Act, the conference agreement inserted the
phrase ``as determined by the State (or the Administrator in the case
of a plan promulgated under [section 110(c) of the Act])'' in the two
places it now appears in that section.\31\ The conference agreement
inserted similar language into the definition of BART in section
169A(g)(2). The 1977 Amendments also added section 110(a)(2)(J) to the
Act, which makes (among other things) a regional haze SIP that meets
the requirements of part C relating to visibility protection a required
part of a state's SIP.
---------------------------------------------------------------------------
\31\ The conference agreement also revised the language ``except
as otherwise provided pursuant to subsection (c), a requirement that
each major stationary source (as defined in section 302(o)) which is
in existence on the date of enactment of this section, but which has
not been in operation for more than 15 years as of such date'' in
H.R. 6161 to its present form. This revision does not affect any
issue raised by the commenter.
---------------------------------------------------------------------------
Thus, H.R. 6161 required states to submit regional haze SIPs
containing BART determinations, but did not explicitly specify that the
BART determinations should, in the first instance, be made by the
state. The conference agreement language clarified that states should
make BART determinations as part of their SIP submittals, as explained
in the conference report:
The agreement clarifies that the State, rather than the
Administrator, identifies the source that impairs visibility in the
Federal class I areas identified and thereby fall within the
requirements of this section. . . . In establishing emission
limitations for any source which impairs visibility, the State shall
determine what constitutes ``best available retrofit technology''
(as defined in this section) in establishing emission limitations on
a source-by-source basis to be included in the State implementation
plan so as to carry out the requirements of this section.
[[Page 5062]]
H.R. Conf. Rep. 95-564, at 155 (1977) (emphasis added). In other
words, BART determinations are a required element (``the State shall
determine'') of a state's regional haze SIP submittal (``to be included
in the State implementation plan''). However, the conference report
does not say that the state's determination is final. For example, it
does not say: ``The State shall determine, and EPA shall abide by . .
.'' Thus, all the conference report says is that states must provide
BART determinations as part of the state's required regional haze
submittal. As the Tenth Circuit Court of Appeals stated, ``All the
conference agreement referenced by the D.C. Circuit did was shift the
initial responsibility for making BART determinations from the EPA to
the state. But that does not differ from other parts of the CAA--states
have the ability to create SIPs, but they are subject to EPA review.''
Oklahoma v. EPA, 723 F.3d 1201, 1209 (10th Cir. 2013).
Another portion of the legislative history, only partially quoted
by the commenter, confirms EPA's supervisory role. Congressman Rogers
inserted into the Congressional Record a Clean Air Conference Report
(1977): Statement of Intent; Clarification of Select Principles. 123
Cong. Rec. 27070 (daily ed. Aug. 4, 1977) (statement of Cong. Rogers).
The Statement of Intent clarified ``some important points on the
intention and effect of the conferees action [that] may have been
overlooked or may be unclear in the text of the conference bill or the
accompanying statement of managers.'' Id. Under section ``D. Visibility
protection,'' the first full paragraph states:
The conferees essentially agreed to the House provision for
visibility protection. The provision was modified to give States a
greater role in identifying sources which are contributing (or may
in the future contribute) to visibility problems and in establishing
control requirements for those sources. However, the conferees
rejected a motion to delete the national goal. The conferees also
rejected a motion to delete EPA's supervisory role under section 110
to assure that the required progress toward that goal will be
achieved by the revised State plan. If a State visibility protection
plan is not adequate to assure such progress, then the Administrator
must disapprove that portion of the SIP and promulgate a visibility
protection plan under section 110(c). Thus, visibility protection in
most mandatory federal Class I areas remains a national commitment,
which is nationally enforceable.
Id. (emphasis added). Thus, the Statement of Intent, instead of
supporting the commenter's arguments, confirms EPA's supervisory role
over states' regional haze SIPs, as the conferees deliberately rejected
a proposal to remove that supervisory role.\32\ The Statement of Intent
also only describes states as having a ``greater role'' in determining
BART; it does not describe that role as exclusive.
---------------------------------------------------------------------------
\32\ In context, the statement regarding ``required progress''
must be understood to include BART. First, the preceding portion of
the statement discusses States' roles in determining controls
generally under 169A(b)(2), ``including'' the BART requirements in
169A(b)(2)(A). The portion about EPA's supervisory role in assuring
``required progress'' should be understood to apply to all of
169A(b)(2), including subsection 169A(b)(2)(A).
---------------------------------------------------------------------------
With respect to Senator Muskie's statements, the comment omits a
portion of the legislative history regarding application of the BART
Guidelines. Oklahoma v. EPA, 723 F.3d 1201, 1209-10 (10th Cir. 2013).
The Tenth Circuit considered those statements in context and confirmed
EPA's authority to ensure that state BART determinations for fossil-
fuel fired power plants having a total generating capacity greater than
750 MW complied with the BART Guidelines. Id. With respect to the
separate views of several Representatives regarding visibility
protection as unrelated to public health, those views are of a small
minority that opposed any provisions for visibility protection
whatsoever. H.R. Rep. 95-294, at 530 (1977). Their views did not carry
the day and, in any case, are irrelevant to the question of EPA's
supervisory role.
With respect to the remainder of the comment regarding various
court opinions, we have responded to similar comments elsewhere. EPA's
action here violates neither the holdings in American Corn Growers and
UARG regarding the RHR, nor the generic remarks regarding cooperative
federalism in the other cited cases.
Comment: Although EPA cites ``errors'' made by Wyoming in its BART
determination for Laramie River Station, EPA has not--and cannot--
demonstrate that any of these alleged ``errors'' represents a violation
of the CAA. These are technical disagreements over judgments committed
by Congress to the states--not grounds for EPA to step in and dictate a
technology choice. Section 169A does not confer any authority upon EPA
to make a BART determination when the state has made one. Once the
state makes a BART determination, EPA's authority to review it in the
SIP review process is very limited. Section 110 mandates that ``[EPA]
shall approve such [SIP] submittal as a whole if it meets all of the
applicable requirements of this chapter.'' 42 U.S.C. 7410(k)(3). See
also Forest Guardians v. Babbitt, 174 F.3d 1178, 1187 (10th Cir. 1999)
(``The Supreme Court and this circuit have made clear that when a
statute uses the word `shall,' Congress has imposed a mandatory duty
upon the subject of the command.'').
As the Fifth Circuit recently expressed, ``the Act confines the EPA
to the ministerial function of reviewing SIPs for consistency with the
Act's requirements,'' and ``[t]h[e] statutory imperative [of section
110(k)(3)] leaves the agency no discretion to do anything other than
ensure that a state's submission meets the CAA's requirements and, if
it does, approve it.'' Luminant, 675 F.3d at 921, 926. See also id. at
932 (``If [the State's] regulations satisfy th[e] basic requirements
[of the CAA], the EPA must approve them, as section 7410(k)(3)
requires. That is the full extent of the EPA's authority in the SIP-
approval process because that is all the authority that the CAA
confers.'') Texas, 690 F.3d at 676 (``[I]f a SIP or a revised SIP meets
the statutory criteria of the CAA, then the EPA must approve it.'');
Bethlehem Steel Corp. v. Gorsuch, 742 F.2d 1028, 1036 (7th Cir. 1984)
(EPA's SIP disapproval power is ``constrained by the substantive
criteria in 42 U.S.C. 7410(a)(2)(A)-(K)''); Fla. Power & Light Co. v.
Costle,650 F.2d 579, 581 (5th Cir. 1981) (``If a SIP or a revised SIP
meets the statutory criteria. . . the EPA must approve it.'')
(citations omitted).
Since Wyoming's BART decision for Laramie River Station, along with
its associated SIP revision, meets the requirements set forth in the
CAA, EPA has no discretion and must approve it in its entirety. As the
Supreme Court explained in the NAAQS context: The Act gives the Agency
no authority to question the wisdom of a state's choices of emission
limitations if they are part of a plan which satisfies the standards of
section 110(a)(2), and the Agency may devise and promulgate a specific
plan of its own only if a state fails to submit an implementation plan
which satisfies those standards. Section 110(c). Thus, so long as the
ultimate effect of a state's choice of emission limitations is
compliance with the national standards for ambient air, the state is at
liberty to adopt whatever mix of emission limitations it deems best
suited to its particular situation. Train, 421 U.S. at 79; see also
Virginia, 108 F.3d at 1408-10 (confirming that the 1977 Amendments to
section 110 did not alter the division of responsibilities recognized
in Train). Accord Union Elec. Co. v. EPA, 427 U.S. 246, 267 (1976)
(``[T]he State has virtually absolute power in allocating emission
[[Page 5063]]
limitations so long as national standards are met.'').
The fact that states must propose SIP revisions ``as may be
necessary'' to achieve reasonable progress does not mean that EPA has
authority to countermand the textual commitment to leave BART decisions
to the states. The D.C. Circuit interpreted similar language in Section
110(k)(5) to constrain EPA's authority over SIP approval and
disapproval. See Virginia, 108 F.3d at 1409. The SIP call provisions of
Section 110(k)(5) similarly state that when a SIP is inadequate ``[EPA]
shall require the State to revise the plan as necessary to correct such
inadequacies.'' But the Virginia court rejected the agency's expansive
view of this phrase as authority to impose specific control measures
for specific emission sources: EPA apparently thinks the ``as
necessary'' language in section 110(k)(5) altered the division of
responsibilities between the states and the agency. We suppose the idea
is that because section 110(k)(5) empowers EPA to ``require the State
to revise the plan as necessary to correct'' inadequacies, it empowers
EPA to require the state to include particular control measures in the
revised plan.
There is nothing to this. Id. at 1409. Instead, the court concluded
that this phrase ``keep[s] EPA within bounds.'' Id. at 1410. Imposition
of a FIP is intended to be a drastic penalty, imposed only where a
state fails to provide the air pollution reductions required by the
CAA, as ``it rescinds state authority to make the many sensitive and
policy choices that a pollution control regime demands.''' Id. at 1406-
07 (citation omitted). The court also expressed, in rejecting EPA's
interpretation of Section 110(k)(5), that ``[w]e would have to see much
clearer language to believe a statute allowed a federal agency to
intrude so deeply into state political processes.'' Id. at 1410.
EPA must therefore approve the Wyoming SIP as it relates to BART at
Laramie River Station, as compliance with the law is all that is
required. See Luminant, 675 F.3d at 926 (EPA's reliance on factors
other than compliance with the CAA in disapproving a SIP violated the
Administrative Procedures Act (APA), as it was ``in excess of statutory
authority,'' and was arbitrary and capricious, as it considered ``a
`factor[ ] which Congress has not intended [the EPA] to consider' '')
(quoting 5 U.S.C. 706(2)(C) and State Farm, 463 U.S. at 43) (alteration
in original).
Response: EPA is not substituting its judgment on required
technology for the State's in this decision. Rather, we have determined
that Wyoming's analysis and determinations were not performed
consistent with the CAA and implementing regulations. EPA considered
the State's SIP as well as the most recent information submitted by
Basin Electric and others for the Laramie River BART units. As
explained in detail in our response to similar comments in the BART
section of this document, we found Basin Electric's estimates of SCR
capital cost deficient in a number of respects, specifically: (1)
Inadequate explanation for the high labor rates that were assumed when
compared to published labor rates; (2) High overtime and per diem costs
without sufficient explanation; (3) Apparent duplication of costs
associated with General Facilities; (4) Inclusion of AFUDC; (5)
Apparent duplication of contingencies and other cost adders; and (6)
Addition of unnecessary SO3 mitigation system. All of these
contributed to excessively high capital cost. Sargent & Lundy also
assumed excessively high cost for replacement catalyst, which
contributes to high operating cost. As we explain elsewhere, these
deficiencies are inconsistent with the CAA and RHR.
We responded to similar comments regarding the remaining comments
above and elsewhere in this document.
Comment: To the extent that the Supreme Court in ADEC suggested it
was adopting a ``reasonableness'' standard, and did not expressly state
that what it was doing was adopting an ``arbitrary and capricious''
standard, the Supreme Court and other federal courts have confirmed
that these two standards are nearly interchangeable. Moreover, to the
extent that there is any perceivable difference between the two
standards, these cases confirm that ``reasonable'' means something more
like ``not arbitrary and capricious'' than ``not what EPA would
prefer.'' See, e.g., Marsh v. Ore. Nat. Res. Council, 490 U.S. 360, 377
n.23 (1989) (``as some of the[ ] courts have recognized, the difference
between the `arbitrary and capricious' and `reasonableness' standards
is not of great pragmatic consequence'') (citing cases); Ridenour v.
Kaiser-Hill Co., 397 F.3d 925, 939 (10th Cir. 2005) (``When a party
challenges agency action as arbitrary and capricious the reasonableness
of the agency's action is judged in accordance with its stated
reasons.'') (citation omitted); Amisub (PSL), Inc. v. Colo. Dep't of
Social Servs., 879 F.2d 789, 800 (10th Cir. 1989) (the court's role in
applying the arbitrary and capricious review standard is ``to determine
if there was a reasonable factual basis to support'' the agency's
findings); United States v. Minnkota Power Co-Op Inc., 831 F. Supp.2d
1109, 1119 (D.N.D. 2001) (expressing that the ``reasonableness''
standard employed by the ADEC Court is the same as the ``arbitrary and
capricious'' standard).
Under the APA's arbitrary and capricious review standard,
administrative action is presumed valid, and review of that action is
`` `narrow in scope.' '' Copar Pumice Co. v. Tidwell, 603 F.3d 780, 793
(10th Cir. 2010) (citation omitted). ``Agency action is arbitrary and
capricious only if the agency `has relied on factors which Congress has
not intended it to consider, entirely failed to consider an important
aspect of the problem, offered an explanation for its decision that
runs counter to the evidence before the agency,' or if the agency
action `is so implausible that it could not be ascribed to a difference
in view or the product of agency expertise.' '' Id. (quoting State
Farm, 463 U.S. at 43). A court will not ``substitute [its] judgment for
that of the agency,'' but will only consider whether the agency
provided a ``reasoned basis'' for its action. Id. at 793-94 (quoting
State Farm, 463 U.S. at 43). The courts also have developed a series of
related standards designed to ensure that courts afford appropriate
deference to an agency's technical and policy choices, and refrain from
substituting the courts' judgment for that of the agency. For the same
reasons that arbitrary and capricious review should apply to EPA's
review of a state BART determination, these related standards also
should apply: (1) The State's BART decision is presumed valid, and EPA
bears the burden of proving otherwise, see Hillsdale Envt'l Loss
Prevention, Inc. v. U.S. Army Corps of Eng'rs, 702 F.3d 1156, 1165
(10th Cir. 2012); (2) the State's decision may be set aside `` `only
for substantial procedural or substantive reasons,' '' id. (citation
omitted); and (3) where experts might disagree about a technical issue,
EPA must defer to the ``reasonable opinions'' of the States' experts,
see Colo. Wild v. U.S. Forest Serv., 435 F.3d 1204, 1214 (10th Cir.
2011). See also Minnkota Power, 831 F. Supp.2d at 1119-20 (the same
principles that apply to court review of agency action under the APA
apply to EPA challenges to state BACT determinations).
EPA's proposal does not formulate or apply these standards, and
thus does not establish grounds to overrule the State's BART
determination for Basin Electric's Laramie River Station. EPA has not
found that Wyoming ``entirely failed to consider an important aspect of
the problem,'' considered factors Congress did not intend it to
consider, or reached a decision ``so implausible''
[[Page 5064]]
as to be arbitrary. Nor has EPA found that Wyoming's explanation for
its decision runs counter to the evidence that was before it. Instead,
EPA complains of minor alleged deviations from broadly worded and
highly flexible guidelines deliberately designed to be consulted but
not rigidly adhered to in any event. EPA therefore must approve the
State's BART decision for Laramie River, as any other result represents
EPA's substitution of its judgment over Wyoming's, which EPA has no
statutory authority to do.
Response: EPA disagrees with this comment, which is based on a
fundamental misunderstanding of EPA's role. In acting on a state's SIP
submittal, EPA does not sit in the position of a reviewing federal
court. Instead, EPA is the agency entrusted by Congress with
administering the CAA. Thus Congress has ``vested EPA with explicit and
sweeping authority to enforce CAA requirements'' and requires that
``EPA step in to ensure that the statutory requirements are honored.''
Alaska Dep't of Envtl. Conservation v. EPA, 540 U.S. 461, 490 (2004).
Reviewing courts, on the other hand, ``are not experts in the field''
and thus defer to decisions by ``the agency charged with the
administration of the statute.'' Chevron, Inc. v. Natural Res. Def.
Council, 467 U.S. 837, 866 (1984).
In the context of acting on a regional haze SIP, EPA must assure
that it meets the requirements of the Act and the RHR, including
requirements regarding BART. EPA--unlike a reviewing court--is not
required to defer to the state's technical judgments. Instead, EPA is
not only authorized, but required to exercise independent technical
judgment in evaluating the adequacy of a state's regional haze SIP,
including its BART determinations, just as EPA must exercise such
judgment in evaluating other SIPs. In evaluating other SIPs, EPA's role
is always to make a judgment about SIP adequacy, not just to meet and
maintain the NAAQS, but also to meet other requirements that do not
have a numeric value. In this case, Congress did not establish NAAQS by
which to measure visibility improvement; instead, it established a
reasonable progress standard and required that EPA assure that such
progress be achieved. Here, contrary to the commenter's assertion, we
are exercising judgment within the parameters laid out in the CAA and
our regulations. Our interpretation of our regulations and of the CAA,
and our technical judgments, are entitled to deference. See, e.g.,
Michigan Dep't. of Envtl. Quality v. Browner, 230 F.3d 181 (6th Cir.
2000); Connecticut Fund for the Env't., Inc. v. EPA, 696 F.2d 169 (2nd
Cir. 1982); Voyageurs Nat'l Park Ass'n v. Norton, 381 F.3d 759 (8th
Cir. 2004); Mont. Sulphur & Chem. Co. v. EPA, 666 F.3d 1174 (9th Cir.
2012).
The comment does not cite to anything in the ADEC opinion (or, for
that matter, in the CAA itself) that suggests EPA must, in reviewing a
SIP submittal, adopt the APA standards of review. Instead, in ADEC the
Supreme Court upheld EPA's position that the State permitting agency's
BACT determination ``did not qualify as reasonable in light of the
statutory guides.'' Alaska Dep't of Envtl. Conservation v. EPA, 540
U.S. 461, 484 (2004). The mere coincidence that some courts have
described the APA standards of review as essentially a
``reasonableness'' standard does not compel EPA to adopt the APA
standards of review; nor did the ADEC opinion suggest EPA must do so.
As explained above, a fundamental difference between EPA and a
reviewing court is that courts lack technical expertise and so
generally defer to agency technical judgments; on the other hand, EPA
is the expert agency entrusted by Congress with administering the CAA
and exercising its best technical judgment in doing so. Another
fundamental difference is that a reviewing court is limited to the
record compiled by the administrative agency, but EPA in its review of
a SIP submittal is not limited just to the record compiled by the state
agency, and may supplement the record with (among other things) EPA's
own expert reports and analyses. In fact, if the cases cited by the
commenter discussing the APA standard of review stand for anything, it
is the proposition that if and when EPA's action on this SIP submittal
is subject to judicial review, the court will base its decision on the
record compiled by EPA and give appropriate deference to EPA's
technical judgments and interpretations of the Act and the RHR.
Accordingly, the Eighth and Tenth Circuit Court of Appeals have applied
the APA standard of review to EPA's actions on other regional haze SIP
submittals. See Oklahoma v. EPA, 723 F.3d 1201 (10th Cir. 2013), North
Dakota v. EPA, 730 F.3d 750 (8th Cir. 2013).
The discussion of the standard of review in the district court's
order and opinion in United States v. Minnkota Power Co-op., Inc., 831
F. Supp. 2d 1109 (D.N.D. 2011), cited by commenter, is not to the
contrary. The district court's opinion first quotes the ADEC opinion
for the proposition that the question presented is whether ``the state
agency's BACT determination was reasonable, in light of the statutory
guides and the state administrative record.'' Id. at 1119 (emphasis
added). The district court's opinion then again quotes the ADEC
opinion: ``We apply the familiar default standard of the Administrative
Procedure Act . . . and ask whether the Agency's action was `arbitrary,
capricious, an abuse of discretion, or otherwise not in accordance with
law.' '' Id. (emphasis added). In the context of the ADEC opinion, the
Agency referred to by the Supreme Court in the second quote is EPA, not
the State agency. The district court's opinion then continues by
quoting a separate Supreme Court opinion discussing the similarities of
the arbitrary and capricious standard and the reasonableness standard.
This fails to establish any sort of connection between the APA standard
and EPA's review of a state determination. In addition, Minnkota Power
took place in the context of an enforcement action, not action on a SIP
submittal. The EPA had entered into a consent decree that (among other
things) ``establishe[d] the standard of review governing the EPA's
challenge to the North Dakota NOX BACT Determination.'' Id.
at 1112. The consent decree provided that ``[t]he disputing Party shall
bear the burden of proof throughout the dispute resolution process.''
Thus, Minnkota Power has nothing to say about use of the APA standard
in EPA's review of a state's BART determination.
Comment: In applying the arbitrary and capricious standard, EPA
should accord the same deference to a state's BART determination that
courts accord to an agency decision under the National Environmental
Policy Act (NEPA), which, like section 169A, ``does not mandate
particular results, but simply prescribes the necessary process.''
Robertson v. Methow Valley Citizens Council, 490 U.S. 332, 350 (1989).
See also 42 U.S.C. 4332(2)(C) (any agency contemplating a ``major
Federal action [that] significantly affect[s] the quality of the human
environment'' must prepare an environmental impact statement [EIS]
analyzing the action's environmental effects). Under NEPA, ``[t]he role
of the courts is simply to ensure that the agency has adequately
considered and disclosed the environmental impact of its actions and
that its decision is not arbitrary or capricious.'' Baltimore Gas &
Elec. Co. v. NRDC, 462 U.S. 87, 97-98 (1983).
The purpose of this deferential review standard under NEPA is to
prevent a court from ``substitut[ing] its judgment for that of the
agency.'' Kleppe v. Sierra Club, 427 U.S. 390, 410 n.21 (1976). As the
Supreme Court explained in Kleppe,
[[Page 5065]]
``[t]he only role for a court is to insure that the agency has taken a
`hard look' at environmental consequences; it cannot `interject itself
within the area of discretion of the executive as to the choice of the
action to be taken.''' Id. (citing NRDC v. Morton, 458 F.2d 827, 838
(D.C. Cir. 1972)).
Under this review standard, ``even if [the reviewing court] would
have made a different choice had the matter been before [the court] de
novo,'' the court ``cannot displace the agencies' choice'' between
conflicting views, evidence, data, and scientific opinions. Custer
Cnty. Action Ass'n v. Garvey, 256 F.3d 1024, 1036 (10th Cir. 2001).
Thus, even in the face of technical objections, a court will uphold the
agency's action so long as it is supported by substantial evidence in
the administrative record, is adequate to foster informed public
participation and decision making, and is not otherwise arbitrary or
capricious. Id.
Moreover, as the courts have repeatedly recognized,
``[d]eficiencies in an EIS that are mere `flyspecks' and do not defeat
NEPA's goals of informed decision making and informed public comment
will not lead to reversal.''' WildEarth Guardians v. NPS, 703 F.3d
1178, 1183 (10th Cir. 2013) (quoting New Mexico v. BLM, 565 F.3d 683,
704 (10th Cir. 2009)). See also Custer Cnty, 256 F.3d at 1035 (``Our
objective is not to `fly speck' the [EIS], but rather, to make a
`pragmatic judgment whether the [EIS]'s form, content and preparation
foster both informed decision-making and informed public
participation.''') (citation omitted).
The same principles apply here, where Congress has expressly
delegated the BART decision to the states, did not mandate the states
to reach a specific outcome, and established only a decision making
process for the states to follow--not a required outcome. If the state
considered all five statutory factors to arrive at a result that
improves visibility, and its decision is not arbitrary, capricious, an
abuse of discretion, or otherwise not in accordance with law, EPA must
affirm the BART selection--even if EPA would or could have made a
different selection.
Response: EPA disagrees with this comment. The comment does not
identify anything in the NEPA court decisions that demonstrates that
those decisions are applicable to EPA's review of a SIP submittal. In
fact, Section 7(c) of the Energy Supply and Environmental Coordination
Act of 1974 (15 U.S.C. 793(c)(1)) exempts actions under the CAA from
the requirements of NEPA. Specifically, this section states that ``[n]o
action taken under the CAA [42 U.S.C. 7401 et seq.] shall be deemed a
major Federal action significantly affecting the quality of the human
environment within the meaning of the National Environmental Policy Act
of 1969 [42 U.S.C. 4321 et seq.].'' While the standard of review for
EPA's SIP and FIP decisions may be similar to that under NEPA,\33\ the
NEPA decisions simply are not applicable in the CAA context.
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\33\ By statute, EPA's promulgation of a FIP must be upheld
unless the court determines EPA's action was ``arbitrary,
capricious, an abuse of discretion, or otherwise not in accordance
with the law.'' CAA Section 307(d)(1)(B), (9)(A). There is no
statutory standard of review governing EPA's disapproval of a SIP,
however, the Supreme Court has held that where the Clean Air Act
does not specific a standard for judicial review, ``we apply the
familiar default standard of the Administrative Procedure Act . . .
and ask whether the agency's action was arbitrary, capricious, an
abuse of discretion, or otherwise not in accordance with law.'' ADEC
at 496-97.
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Furthermore, NEPA relies solely on ``procedural mechanisms--as
opposed to substantive, result-based standards.'' Robertson v. Methow
Valley Citizens Council, 490 U.S. 332, 353 (1989). Unlike NEPA, the
CAA's regional haze program has specific substantive requirements, and
EPA must ensure that SIP submittals meet the requirements of the Act,
including the substantive provisions of the regional haze program. See
CAA Section 110(a)(2)(J) (SIP submittals must meet applicable
requirements of Part C of title I, including visibility protection). As
the Eighth Circuit Court of Appeals stated: ``EPA is left with more
than the ministerial task of routinely approving SIP submissions.''
North Dakota v. EPA, 730 F.3d 750 (8th Cir. 2013) (emphasis added).
Comment: One commenter asserted that the U.S. Supreme Court and the
lower federal courts have long recognized and applied the principle of
``harmless error'' where an agency may have committed an error, but
that error did not affect the outcome of its decision. See, e.g., Nat'l
Ass'n of Home Builders v. Defenders of Wildlife, 551 U.S. 644, 659
(2007); Hillsdale, 702 F.3d at 1165. See generally 5 U.S.C. 706
(``[D]ue account shall be taken of the rule of prejudicial error.'').
The commenter argued that the courts also have long recognized the
related principle that agencies may ``overlook circumstances that in
context may fairly be considered de minimis,'' as part of the broad
notion that ``the law does not concern itself with trifling matters.''
Alabama Power Co. v. Costle, 636 F.2d 323, 360 (D.C. Cir. 1979). Thus,
for instance, the D.C. Circuit rejected a challenge to a Federal
Aviation Administration rule where the agency had used ``inappropriate
guidelines for measuring the effects of noise'' in its determination
that a proposed airport site would not result in any ``use'' of a
nearby wildlife refuge. Allison v. Dep't of Transp., 908 F.2d 1024,
1026 (D.C. Cir. 1990). The court cited the APA provision requiring
consideration of ``prejudicial error,'' and expressed that ``[a] court
should not upset a decision because of errors that are not material.''
Id. at 1029 (citations omitted). See also Grunman Data Sys. Corp. v.
Widnall, 15 F.3d 1044, 1048 (Fed. Cir. 1994) (rejecting bid protest
although agency may have violated accounting principles in its analysis
of the best value bid, as any accounting errors were ``de minimis,''
and stating that ``overturning awards on de minimis errors wastes
resources and time, and is needlessly disruptive of procurement
activities and governmental programs and operations'') (citation
omitted).
Finally, the commenter argued, the courts have repeatedly held that
agency action should not be reversed due to mere calculation errors
that do not render a rule arbitrary and capricious. See, e.g., Michigan
v. EPA, 213 F.3d 663, 691 (D.C. Cir. 2000) (rejecting challenge to EPA
decision despite error in calculation); Chem. Mfrs. Ass'n v. EPA, 870
F.2d 177, 241, clarified on reh'g, 885 F.2d 253 (5th Cir. 1989) (same);
CPC Int'l, Inc. v. Train, 540 F.2d 1329, 1343-44 (8th Cir. 1976)
(same). The commenter stated that these same principles should apply to
EPA's review of the State's BART determinations, such that EPA has no
authority to disapprove the State's decisions if a deviation from the
BART Guidelines and CCM was merely de minimis and at most harmless
error that did not affect the State's selection of BART. Indeed, EPA's
approach itself suggests that the BART Guidelines and CCM were intended
to be flexible, and that EPA's review of compliance with their
provisions is subject to a materiality standard. For instance, in the
Proposed Rule, EPA proposes to disapprove certain BART determinations
based on purported deviations from the BART Guidelines and CCM in
assessing cost and visibility, yet it also proposes to approve other
BART determinations ``because [it has] determined that the State's
conclusions were reasonable despite the cost and visibility errors''
identified by EPA. 78 FR 34750. And, while the Tenth Circuit's decision
in Oklahoma v. EPA is not yet final, as petitions for rehearing may yet
be filed, that court similarly suggested that there
[[Page 5066]]
was a materiality element to a state's compliance with the BART
Guidelines, noting, in particular, that the State's cost estimates were
``more than ten times EPA's stated average costs per ton for th[e]
technology, and nearly five times as much as the upper limit of EPA's
expected cost range.'' --F.3d--, 2013 U.S. App. LEXIS 14634, at *25
(10th Cir. July 19, 2013). Notably, that case did not involve SCR
technology, which the CCM affords a greater amount of flexibility in
assessing, and the State had failed to note and explain its deviations
from the CCM.
By applying these principles here, the commenter asserted, any
deviation from the BART Guidelines and CCM was de minimis, and mere
harmless error. Certainly, EPA has not shown that the State would have
made a different BART selection had it assessed the cost and visibility
factors in the manner EPA suggests--particularly as the selection of
BART must be made by weighing all five factors, and as the differences
between the State's and EPA's assessments of cost and visibility are
not so substantial as to necessitate a different result. In other
states, EPA has acknowledged that a state's BART determination may be
disapproved on account of a claimed error only if the error would have
changed the BART determination. In approving Colorado's regional haze
SIP, EPA did not disapprove the BART determination for the Martin Drake
power plant, despite EPA's disagreement regarding the control
efficiency of SCR because the discrepancy would not have changed the
outcome. 77 FR 76871, 76875-76 (Dec. 31, 2012) (``[We] find that it was
not unreasonable for Colorado to use 0.07 lb/MMBtu to model the
predicted visibility improvement from SCR. Moreover, while we do agree
that assuming a control efficiency of 0.05 lb/MMBtu would have resulted
in greater modeled visibility benefits, we do not agree that the
difference in visibility benefits would have led Colorado to a
different conclusion given the magnitude of the benefits associated
with SCR.''). The commenter advocated that EPA should take a similar
approach in Wyoming.
The commenter finished by stating that if there is a question as to
whether the State might have made a different BART selection had it
assessed cost and visibility in the manner suggested by EPA, EPA should
return the issue to the State to reweigh the BART factors with that
information. See SKF USA Inc. v. United States, 254 F.3d 1022, 1029
(Fed. Cir. 2001) (courts may remand matters to the agency upon request
to correct ``clerical errors, transcription errors, or erroneous
calculations'').
Response: The cases cited to by the commenter all concern standards
by which courts evaluate agency action, not standards by which EPA, an
administrative agency, evaluates SIP submissions for compliance with
the requirements of the CAA. The cases are therefore inapposite.
Nevertheless, in situations where a state's SIP reaches a reasonable
result overall despite violations of certain statutory or regulatory
requirements, EPA believes that approving the SIP is sometimes a better
use of scarce administrative resources and more in line with principles
of cooperative federalism than promulgating a FIP. This approach is
arguably similar to the principle of ``harmless error'' that courts
adhere to in the context of judicial review.
In this situation, however, the errors committed by Wyoming in its
regional haze SIP were neither harmless nor de minimis. As we have
explained previously, because Wyoming did not properly calculate the
costs of the various control options or accurately estimate the
visibility improvement associated with these controls, the State's
ultimate selection of BART for several EGUs did not represent the best
system of continuous emission reduction. As the Eighth and Tenth
Circuits have recently held, EPA acts within its power under section
169A of the CAA when it rejects a BART determination on the basis that
a state did not properly take into consideration the costs of
compliance as a result of methodological or data flaws. See Oklahoma v.
EPA, 723 F.3d 1201, 1212 (10th Cir. 2013); North Dakota v. EPA, 730
F.3d 750 (8th Cir. 2013). This same reasoning applies equally to the
other statutory BART factors, such as visibility improvement.
We also disagree with the commenter that our action on the Colorado
regional haze SIP implies that a similar outcome is warranted here. In
that action, we stated that ``it was not unreasonable for Colorado to
use 0.07 lb/MMBtu to model the predicted visibility improvement from
SCR.'' 77 FR 76871, 76875 (Dec. 31, 2012). Thus, we did not disagree
with Colorado's choice of control efficiency, as the commenter claims,
and the situation bears no relationship to this one, where we have
carefully explained our disagreement with multiple aspects of Wyoming's
NOX BART determinations.
Finally, we decline to ``return the issue to the State,'' as the
commenter proposes. At this time, the Wyoming regional haze SIP is many
years overdue, and the deadline for EPA to issue a FIP has long since
passed. We note, however, that Wyoming is free to submit a SIP revision
at any time that, if approved, could replace all or a portion of EPA's
FIP.
Comment: EPA's proposal to disapprove Wyoming's BART determination
for Laramie River not only overrides the State's technical judgment but
also renders moot with a stroke of a pen the extensive judicial,
administrative, and political processes developed by the State to
implement its obligations under the CAA as a separate sovereign.
Wyoming has enacted a robust and independent set of administrative and
judicial procedures to review and potentially overturn BART decisions
made by the State. These procedures are part of the State's SIP
expressly approved by EPA, 40 CFR 52.2620, making them federally
enforceable.
Wyoming's air quality regulations require a source subject to BART
to apply for and obtain a BART permit. In this case, Laramie River
Station's BART permit was issued pursuant to Wyoming Air Quality
Standards and Regulations (WAQSR) Chapter 6, Sections 2 and 9. The
rules requiring BART permits in Wyoming were adopted on October 9, 2006
as a new section to meet the requirements of EPA's RHR. Chapter 6
requires facilities seeking permits to comply with all the rules and
regulations of Wyoming. Chapter 6, Section 9 of the Air Quality
Division's rules and regulations govern BART permits. Section 9(e)(iv)
requires that the opportunity for public comment on BART permits follow
the procedures specified in Chapter 6, Section 2(m). That section, in
turn, establishes a notice and comment procedure that specifically
requires a copy of the public notice to be sent to EPA. Thus, EPA
approved Wyoming's plan that specifically contemplates EPA's inclusion
in State administrative review proceedings. See 40 CFR 52.2620; see
also US Magnesium, LLC v. EPA, 690 F.3d 1157, 1159 (10th Cir. 2012)
(EPA's approval of a State's SIP gave the SIP the force and effect of
federal law).
Here, EPA received the required notice at every step of the
proceedings. EPA, however, chose to participate to only a limited
extent. After submitting August 3, 2009 comments to the State's BART
Application Analysis and proposed permit and October 26, 2009 comments
to Wyoming's draft regional haze SIP, EPA excised itself from the
process. Despite its prior comments on Basin Electric's BART permit and
the regional haze SIP, EPA did not seek to intervene in Basin
Electric's administrative appeal to the
[[Page 5067]]
Environmental Quality Council or comment on Basin Electric's settlement
agreement with the Environmental Quality Council. EPA could have
advised the Environmental Quality Council that it believed the proposed
settlement violated the CAA or was otherwise arbitrary and capricious,
but it did not. Instead, illustrating its disregard for State primacy,
EPA now proposes to disapprove the NOX BART emissions limits
in the settlement agreement and final SIP, years after the
administrative process concluded.
As the dissenters in ADEC described, EPA should not be permitted to
avoid a ``more painstaking state process by a mere stroke of the pen
under the agency's letterhead.'' 540 U.S. at 509 (Kennedy, J.,
dissenting) (discussing an analogous process for BACT determinations).
The CAA's ``strict'' division of authority creates a ``statutory
federalism bar [that] prohibits EPA from using the SIP process to force
States to adopt specific control measures.'' EME Homer City Generation,
L.P. v. EPA, 696 F.3d 7, 29 (D.C. Cir. 2012) (citing Virginia, 108 F.3d
at 1410). But that is precisely what EPA seeks to do here. EPA's
approach both confuses the CAA ``with a general administrative law
statute like the [APA]'' and upsets ``the balance between State and
Federal Governments.'' See ADEC, 540 U.S. at 507-17 (Kennedy, J.,
dissenting). Simply put, it is inappropriate for EPA to dodge the
administrative and judicial review process established in the State of
Wyoming through overturning of Wyoming's BART decision by
administrative fiat. See id. at 510 (Kennedy, J., dissenting). It was
only after Wyoming submitted its regional haze SIP to EPA that EPA
announced it found the settlement ``unreasonable'' and something with
which it ``disagreed.'' Based upon these assertions, and without
demonstrating that the BART permit actually violates the CAA, EPA now
proposes to void all the extensive administrative proceedings,
processes, comment periods, and permit finality accorded under State
law.
This improperly impinges upon state authority. Under the regional
haze program, deference to state authority is far more compelling than
issues related to public health under the BACT program, and so the
Supreme Court's holding in ADEC that EPA may not require ``recourse to
state processes'' is inapplicable to BART decisions. ADEC, 541 U.S. at
492. EPA should conduct itself in accordance with the spirit of its
representation to the Supreme Court that it has never sought to
override a state court judgment, and should not seek to override a
state BART decision that has been litigated to administrative
conclusion under state law, particularly where, as here, EPA never
advised the State adjudicators or the parties to the State proceedings
that it considered the permit to be invalid under the CAA. EPA could
have participated in the State administrative appeal proceeding or, at
a minimum, appeared in the proceeding to register an objection to the
settlement agreement. Having elected not to do so, EPA should respect
the result of the State's process. Alternatively, EPA is precluded from
overruling the Laramie River BART permit decision that resulted from
that process. ADEC, 540 U.S. at 491 n.14. EPA had notice and ample
opportunity to contest the appropriateness and legality of the BART
permit in Wyoming, but simply chose not to do so.
EPA is not free to let parties like Basin Electric spend thousands
of dollars and years of effort resolving the terms of a BART permit,
only to find the process wasted because EPA disagrees yet chose to
ignore multiple notices of the State proceedings. Absent application of
claim preclusion under these circumstances, EPA could effectively
``rescind[ ] state authority to make the many sensitive and policy
choices that a pollution control regime demands.'' Virginia, 108 F.3d
at 1406-07 (citation omitted). Here, EPA does not intrude upon state
political processes; it ignores them, upsetting ``the balance between
State and Federal Governments.'' See ADEC, 540 U.S. at 507-17 (Kennedy,
J., dissenting).
EPA's interference with State's prerogatives also violates the
Tenth Amendment to the United States Constitution. ``[T]he Tenth
Amendment confirms that the power of the Federal Government is subject
to limits that may, in a given instance, reserve power to the States.''
New York v. United States, 505 U.S. 144, 157 (1992). See also U.S.
Const. amend. X (``The powers not delegated to the United States by the
Constitution, nor prohibited by it to the States, are reserved to the
States respectively, or to the people.''). Here, EPA's rejection of
Wyoming's BART decision and imposition of its own not only overrides
Congress' resolution to leave localized BART analyses in the hands of
the states, but also infringes on Wyoming's (and its citizens') Tenth
Amendment right to have those decisions made and adjudicated by the
State. See Arlington, 133 S.Ct. at 1874 (although Chevron deference
generally applies to an agency's interpretation of the scope of its
authority, ``[w]here Congress has established a clear line, the agency
cannot go beyond it; and where Congress has established an ambiguous
line, the agency can go no further than the ambiguity will fairly
allow''); Hodel v. Va. Surface Min. & Reclamation Ass'n, 452 U.S. 264,
289 (1981) (statute survived Tenth Amendment scrutiny because it
``establishes a program of cooperative federalism that allows the
States, within limits established by federal minimum standards, to
enact and administer their own regulatory programs, structured to meet
their own particular needs,'' instead of ``commandeer[ing] the
legislative processes of the States by directly compelling them to
enact and enforce a federal regulatory program'').
Earlier comments provided similar arguments, by noting that Wyoming
issued its BART Application Analysis and proposed permit on May 28,
2009, and accepted public comments on its analysis and proposed permit
for a period of 60 days, followed by a public hearing on August 6,
2009. Numerous comments were received, including comments from EPA
dated August 3, 2009. EPA did not comment that Wyoming's proposed BART
determination violated the CAA. Nor did EPA identify any action taken
by Wyoming in connection with the permit that was arbitrary or
capricious. While EPA regularly encouraged Wyoming to consider both
SNCR and SCR technologies, at no point did EPA advise Wyoming that BART
controls of LNBs and OFA for the Laramie River Station would violate
the CAA or otherwise be arbitrary and capricious. Basin Electric
appealed its BART permit to the Environmental Quality Council, arguing
that Wyoming's imposition of additional technology requirements in 2018
as part of its long term goals exceeded its authority for terms
contained in a BART permit. In its appeal, Basin Electric accepted LNB
and OFA as BART but objected to the additional permit condition related
to long term strategies.
Basin Electric served its Petition for Review before the
Environmental Quality Council on EPA, and EPA received this notice of
appeal, as indicated by its acceptance of the certified mail forwarding
the appeal. Thereafter, EPA chose not to comment or otherwise
participate in Basin Electric's appeal and never informed the parties
or the Environmental Quality Council that EPA considered Wyoming's BART
decision to violate the CAA. In fact, no contention was made, by any
person or entity, that the BART permit issued by Wyoming violated the
CAA.
After litigation, Basin Electric's appeal was settled. Wyoming
agreed to remove the provision related to future
[[Page 5068]]
control strategies in exchange for Basin Electric's agreement to reduce
emission levels further than those proposed in the original permit and
provide even further reductions by the end of 2017. This proposed
settlement was presented to the Environmental Quality Council for
approval. No persons or entities objected to the proposed settlement,
including EPA.
Only after Wyoming's regional haze SIP was submitted to EPA did EPA
announce that it found the settlement ``unreasonable'' and something
with which it ``disagreed.'' Based upon these assertions, and without
demonstrating that the BART permit actually violates the CAA, EPA now
proposes to void all of the extensive administrative proceedings,
processes, comment periods and permit finality accorded under state
law.
This violates the explicit representations EPA made to the United
States Supreme Court that decisions to over-ride state technology
choices are rarely undertaken and therefore do not pose a threat to
state adjudicative processes. In footnote 14 of the ADEC decision, the
Court quoted EPA for the proposition that EPA has engaged in
``restrained and moderate'' use of its authority to overrule specific
technology choices and has never ``asserted authority to override a
state-court judgment.'' Based upon this understanding, the majority in
ADEC dismissed concerns expressed by the dissent about state/federal
relations, stating that ``[e]xperience . . . affords no grounding for
the dissent's predictions that EPA oversight . . . will `rewor[k] . . .
the balance between State and Federal Governments' and threaten state
courts' independence.'' ADEC, 540 U.S. at 493 n. 16. With its proposed
action here, however, EPA is doing precisely what the dissent in ADEC
predicted, ignoring the extended contested case process afforded under
state law and the final administrative litigation resolution reached
under state law.
While Basin Electric's appeal ended short of a court proceeding,
the distinction between a litigated judgment in an administrative
appeal and a judgment in a state court proceeding is not significant.
In both cases, EPA's proposed action fails to respect the cooperative
federalism that underlies the CAA in general. Under the RHR deference
to state authority is far more compelling than issues related to public
health under the BACT program, and so the Supreme Court's holding in
ADEC that EPA may not require ``recourse to state processes'' is
inapplicable to BART decisions. ADEC, 541 U.S. at 492. EPA should
conduct itself in accordance with the spirit of its representation to
the Supreme Court that it has never sought to override a state-court
judgment, and should not attempt to override a state BART decision that
has been litigated to an administrative conclusion under state law
particularly where, as here, EPA never advised the state adjudicators
or the parties to the state proceedings that it considered the permit
to be invalid under the CAA. EPA could have participated in the State
administrative appeal proceeding or at a minimum appeared therein to
register an objection to the settlement agreement. Having elected not
to do so, EPA should respect the result of the State's process.
Response: EPA disagrees with this comment. As an initial matter, as
provided in detail elsewhere in this section and in the docket for this
action, we provided feedback to the State in our comment letters on the
proposed SIP and in meeting with State and company officials;
therefore, the State and companies were aware of our expectations.
That WAQSR Chapter 6, Section 2 has been approved into the SIP does
not somehow commit EPA to participate in Wyoming's BART permit process.
The Act and the RHR do not require that BART be determined through a
permit process that is subject to administrative appeal or through a
permit process at all. The SIP-approved provision in Chapter 6, Section
2 for notice to EPA of permit actions meets the requirements of 40 CFR
51.161(d), regarding public procedures for review of new or modified
sources, not BART sources. Furthermore, nothing in Chapter 6, Section 2
suggests that notice to EPA of a permit process somehow binds EPA to
participate in that process.
The commenter provides no statutory, regulatory, or judicial
authority to support the proposition that EPA must participate in state
administrative or judicial procedures. With respect to state judicial
procedures, the Supreme Court has stated: ``[i]t would be unusual, to
say the least, for Congress to remit a federal agency enforcing federal
law solely to state court.'' Alaska Dep't of Envtl. Conservation v.
EPA, 540 U.S. 461, 493 (2004). Thus the Court ``decline[d] to read such
an uncommon regime into the [CAA].'' Id. The commenter's notion that
the ADEC opinion (which concerned a BACT determination under the PSD
program) is inapplicable to BART determinations, merely because BART
determination are part of a program to improve visibility rather than
public health, finds no support in the ADEC opinion or anywhere in the
CAA. We elsewhere respond to comments that argue that the language of
the CAA itself requires a greater level of deference to states BART
determinations.
With respect to the dissent in ADEC, that dissent of course does
not represent the opinion of the Supreme Court. Nonetheless, EPA is not
undoing the State's process through the ``mere stroke of a pen on the
Agency's letterhead,'' but instead is acting on the State's regional
haze submittal through notice-and-comment rulemaking that is
potentially subject to judicial review. Furthermore, EPA is not
confusing the CAA with the APA; our authority and duty to review the
State's regional haze SIP for compliance with the CAA and the RHR stems
from the CAA itself. As we discuss elsewhere, EPA's role in reviewing
SIPs differs in many key aspects from that of a court reviewing agency
action under the APA.
Under the CAA, states are required to submit SIPS that contain
emissions limits necessary to protect visibility, and EPA is required
to disapprove of any inadequate SIPs and promulgate FIPs in their
place. 42 U.S.C. 7491(b)(2); Section 7410(c)(1)(A). The CAA does not
require EPA to participate in state proceedings related to its SIP
submission, nor does it preclude EPA from carrying out its statutory
duty to disapprove an inadequate SIP if EPA does not participate in
state proceedings. The notion that BART determinations are insulated
from EPA review simply because the State has an administrative appeal
process not only has no support in the Act, it is contrary to the
purposes of the Act and EPA's express obligation to approve only SIP
submittals that meet the requirements of the Act.
Moreover, any state BART decisions made under an unapproved SIP are
not federally enforceable because any SIP ``shall not be treated as
meeting the requirements of this chapter until the Administrator
approves the entire plan revision as complying with the applicable
requirements.'' 42 U.S.C. 7410(k)(3); see also Gen. Motors Corp. v.
United States, 496 U.S. 530, 540 (1990) (holding EPA may bring
enforcement action under an existing SIP while a SIP proposal is
pending).
Finally, this action does not violate the Tenth Amendment. The
Supreme Court has explained that ``where Congress has the authority to
regulate private activity under the Commerce Clause, we have recognized
Congress' power to offer States the choice of regulating that activity
according to federal standards or having state law pre-empted by
federal regulation.'' New
[[Page 5069]]
York v. United States, 505 U.S. 144, 167 (1992); see also U.S. Const.
Art. I, Section 8, cl. 3 (commerce clause); id. Art. VI, cl. 2
(supremacy clause). The commenter does not argue that the CAA is
outside of Congress' Commerce Clause authority. Through the SIP/FIP
mechanism, the Act offered Wyoming the choice of regulating sources in
the State in accordance with the regional haze provisions in the CAA
and with rules promulgated by EPA under its CAA authority; thus the Act
itself does not violate the Tenth Amendment. With respect to this
particular action, our disapproval of Wyoming's regional haze SIP and
our FIP compel no action on the part of the State and are not coercive
vis-a-vis the State. As explained elsewhere in these responses, EPA has
not required Wyoming to adopt specific control measures. Instead, our
FIP contains requirements applicable only to some private companies.
The Tenth Amendment is not implicated by our action.
Comment: Even if EPA can contravene the state process, it should
still require compelling circumstances demonstrating a plain and
unambiguous violation of the CAA before it countermands a state
proceeding. Such a showing is necessary to preserve the balance between
Federal and state governments under the CAA. EPA is undermining the
significance and integrity of the State appeals process as well as the
State's authority to determine BART. EPA is also making it possible for
interested parties, including environmental groups, to ignore their
procedural obligation to voice objections under State law because they
can wait to raise them when EPA acts on a proposed SIP. EPA chose not
to participate in the BART permit process and the resulting appeals,
despite knowing that the very NOX control equipment at issue
in the regional haze FIP was being determined. Under the principles of
comity, EPA should be barred from now addressing these issues at this
late period. Under these circumstances, EPA should not be allowed to
raise complaints with a BART permit for the first time in the federal
proceeding. Failure to do so diminishes State law and puts parties like
Basin Electric into a position where they must pursue State remedies to
avoid finality under State law but find that such actions mean nothing
in the end under the federal process.
Response: EPA disagrees with this comment. Nothing in the CAA sets
some sort of ``compelling circumstance'' standard for disapproval of a
SIP. Instead, we have the duty to ensure that regional haze SIP
submittals meet the requirements of the Act and the RHR. See CAA
Section 110(a)(2)(J) (SIP submittals must meet applicable requirements
of Part C of title I, including visibility protection). We do not agree
that we are prohibited from identifying deficiencies in the Wyoming SIP
after the State rulemaking process is complete, and the commenter cites
nothing in the Act to the contrary. Furthermore, many of the concerns
raised in this action were communicated to the State in our comment
letters and in numerous meetings with State officials. With respect to
comments we have received from environmental organizations on our
proposed action on Wyoming's SIP, the CAA does not require those
organizations to participate in state processes.\34\ EPA is taking
actions specified under the CAA in partially approving and partially
disapproving the Wyoming SIP. The CAA also specifies the responsibility
of EPA to issue a FIP when states have not met their requirements under
the CAA. EPA is promulgating this FIP to fill the regulatory gap
created by the partial disapproval. Under the FIP, the State retains
its authority to submit future regional haze SIPs consistent with CAA
and RHR requirements; we do not discount the possibility of a future,
approvable SIP submission that results in the modification or
withdrawal of the FIP. This rulemaking does not change the distribution
of power between the states and EPA.
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\34\ In contrast, elsewhere in the Act Congress has made it
explicit that participation in state processes is required in order
to raise objections with EPA. See CAA section 504(b)(2).
---------------------------------------------------------------------------
Comment: BART applies to specific emission sources and requires
consideration of facts applicable to specific source locations. Unlike
a rule, or a SIP generally, a BART determination effectively
adjudicates the specific rights and legal obligations of individual
emissions sources. This typically entitles individual source owners to
substantive procedural rights and remedies under state law when a BART
determination is made. In Wyoming, for example, each individual source
is required to apply for a BART Permit. Wyoming law affords the source
being regulated with special opportunities to be heard, both as part of
the public review of a permit application and, in the case of a permit,
in an adjudicative hearing with opportunities to challenge factual
determinations, call and question witnesses, and present evidence. When
an applicant applies for a BART construction permit, the applicant is
afforded the opportunity to present its own views and responses to
comments to the state agency. If a permit is issued or denied, the
applicant can appeal the permit decision to the Environmental Quality
Council, which has statutory authority to amend, grant, modify, or deny
the permit. Wyo. Stat. Section 35-11-802. This proceeding is conducted
as a contested case, affording the applicant the right to cross-examine
the Environmental Quality Council's technical experts regarding their
BART assumptions and conclusions.
The applicant also can call its own experts and witnesses. Wyo.
Dep't of Envtl. Quality Rules and Regulations, Wyo. Admin. Code ENV PP
Ch. 2 Sections 1-14. With these procedures, BART permit applicants can
challenge the cost estimates and assumptions underlying a BART permit
decision, including making a showing, as Basin Electric does here by
comment only, that EPA's consultants have ignored critical site-
specific conditions.
EPA's effort to impose BART determinations by federal rulemaking
impermissibly deprives source owners of these substantive procedural
rights afforded under State law. This is one reason courts have taken a
strong stance against EPA imposing specific control technologies
through partial approval of a SIP. Leaving site-specific decisions in
the hands of the states provides state-sponsored procedural rights for
the individually regulated sources. See Virginia, 108 F.3d at 1406-10;
Michigan v. Thomas, 805 F.2d 176, 186 (6th Cir. 1986); Bethlehem Steel
Corp., 742 F.2d at 1035-37 (all holding that EPA may not render a state
SIP more stringent than intended by the state by partial SIP approval
or imposition of control technologies). A BART determination requires
consideration of complex, case-specific control technologies and makes
fact-dependent determinations for individual named sources, which
effectively makes the federal BART determination an administrative
order directed specifically at Basin Electric rather than a rule
generally applicable to the public. Under these circumstances, EPA
cannot order specific emission limits and consequent expensive control
technologies without affording Basin Electric a hearing at which it can
cross examine EPA's consultants. Basin Electric must also be given an
opportunity to challenge EPA's interpretation of the facts. When EPA
moves from a quasi-legislative function to a quasi-judicial function,
as it has by making fact-based determinations for specific, named
sources, it must provide the required procedural protections for those
affected by its actions. See
[[Page 5070]]
Londoner v. City & Cnty. of Denver, 210 U.S. 373, 386 (1908) (requiring
an agency to provide notice and an adjudicative hearing for individuals
suffering specific injury from an agency rule); compare Amoco Oil Co.
v. EPA, 501 F.2d 722, 734-35 (D.C. Cir. 1974) (agency action was quasi-
legislative because it did not rely on ``findings of fact'' and
evidence to make determinations for a single source).
One administrative law expert designated the distinction between
rule making and adjudication as ``perhaps the most critical distinction
in all of administrative law.'' Gary Lawson, Federal Administrative Law
10 (American Casebook Series, Thomson-West 4th ed. 2007). It is an
important distinction because it separates agency decisions that
function as policy from those that make situational determinations. ``A
plain[ ] instance of administrative adjudication occurs where an
administrative agency at one and the same time makes a rule and applies
it to a concrete situation . . . The essential difference between
legislation and adjudication is not that one looks to the future and
the other to the past . . . What distinguishes legislation from
adjudication is that the former affects the rights of individuals in
the abstract and must be applied in a further proceeding before the
legal position of any particular individual will be definitely touched
by it; while adjudication operates concretely upon individuals in their
individual capacity.'' John Dickinson, Administrative Justice and the
Supremacy of Law in the United States 16-21 (Harvard University Press
1927), quoted in Gary Lawson, Federal Administrative Law 10-11(American
Casebook Series, Thomson-West 4th ed. 2007).
In the Proposed Rule, EPA makes specific factual findings about
individual sources. EPA relies on its expert consultant Andover to draw
specific factual conclusions about retrofit construction costs for
Laramie River, yet it affords Basin Electric no opportunity to confront
its expert over the Andover Report's error-filled findings. In order to
provide due process, a specific party like Basin Electric who is
singled out and subjected to EPA's fact-based determinations must be
allowed ``the right to support his allegations by argument however
brief[,] and, if need be, by proof, however informal.'' Londoner, 210
U.S. at 386. In the case of Laramie River, the requirement for a
hearing is especially strong because ``[t]he extent to which procedural
due process must be afforded the recipient is influenced by the extent
to which he may be `condemned to suffer grievous loss.' '' Goldberg v.
Kelly, 397 U.S. 254, 262-63 (1970) (citing Joint Anti-Fascist Refugee
Comm. v. McGrath, 341 U.S. 123, 168 (1951)).
EPA must afford these procedural rights to Basin Electric if EPA is
going to assume control over site-specific BART determinations, rather
than leave them to the states as Congress intended. Section 169A's
directive that BART be determined by the states permits states to
afford individual emissions sources the procedural and other rights
that due process requires for site-specific regulation, and EPA must
afford these same rights to source owners if it is going to federalize
the BART program by rejecting all state determinations with which its
technical consultants disagree.
Response: EPA disagrees with this comment. EPA's procedures did not
deprive Basin Electric of due process. First, the comment confuses the
issues by arguing that under State law Basin Electric has ``substantive
procedural rights'' and that EPA's procedures somehow deprived Basin
Electric of these. But due process under the Fifth Amendment does not
require EPA to give exactly the same process that the State gave. The
commenter provides no authority for the existence of something called a
state ``substantive procedural right'' that the United States is bound
by the Fifth Amendment to respect.\35\ Instead, federal due process
protects substantive fundamental rights and procedural rights if the
claimant has a constitutionally protected life, liberty, or property
interest. See U.S. Const., Amend. V (``nor be deprived of life,
liberty, or property, without due process of law''). That the comment
attempts to make a state procedure into a constitutionally protected
interest by calling it a ``substantive procedural right'' is of no
avail; the comment identifies no attribute of the state procedure that
makes it into a constitutionally protected ``life, liberty, or
property'' interest under either the text of the Fifth Amendment or the
case law interpreting that Amendment. See Cleveland Bd. Of Educ. v.
Loudermill, 470 U.S. 532, 541 (1985) (``[T]he Due Process Clause
provides that certain substantive rights--life, liberty, and property--
cannot be deprived except pursuant to constitutionally adequate
procedures. The categories of substance and procedure are distinct.'').
Nor does Basin Electric have a protected interest in the outcome of the
State BART permit process. There is no ``legitimate claim of
entitlement'' to that outcome, Board of Regents of State Colleges v.
Roth, 408 U.S. 564, 577 (1972), as the State's BART determination was
always subject to review by EPA under the CAA. In the end, what the
Fifth Amendment does potentially protect is Basin Electric's property
interest itself, not the State procedure. As we now explain, EPA's
procedures were sufficient to satisfy the requirements of due process
with respect to Basin Electric's property interest.
---------------------------------------------------------------------------
\35\ The cases cited by the commenter, Virginia, 108 F.3d at
1406-10; Michigan v. Thomas, 805 F.2d 176, 186 (6th Cir. 1986);
Bethlehem Steel Corp., 742 F.2d at 1035-37, lack any reference to a
notion of ``state substantive procedural rights'' or ``state-
sponsored procedural rights.'' The opinion in Virginia concerns the
roles EPA and states play under the Act; the opinion does not
discuss due process for owners of individual sources. The opinion in
Michigan, noting that EPA's action had a rational basis, briefly
dismisses a claim that the action violated the due process clause of
the Fifth Amendment by discriminating against business and industry.
Michigan, 805 F.2d at 185 n.1. Although the opinion does not make it
explicit, the claim there thus seems to have been equal protection
as incorporated into the Fifth Amendment, not procedural due
process. See Bolling v. Sharpe, 347 U.S. 497 (1954). Michigan is not
on point. Finally, the dicta in Bethlehem Steel speculates that, in
the case of a FIP, ``EPA might have had to give interested persons
an opportunity to submit oral as well as written comments,''
Bethlehem Steel, 742 F.2d at 1032, which EPA did in this case. The
dicta, which in any case is not binding, does not say that EPA's
experts must be available for cross-examination or that EPA is bound
by state procedures or that the Fifth Amendment to the U.S.
Constitution recognizes state ``substantive procedural rights.''
---------------------------------------------------------------------------
CAA section 307(d) specifies the procedures that EPA is required to
follow in promulgating a FIP. Section 307(d) does not require
adjudicatory hearings, nor does it require EPA to allow for cross-
examination of EPA's consultants.\36\ Additionally, the Administrative
Procedure Act only requires adjudicatory hearings if a particular
statute specifies that a rule must be made ``on the record after an
opportunity for an agency hearing.'' \37\ No such requirement is
contained in section 307(d).\38\ The Supreme Court has explained that
courts face an extremely high burden in order to impose additional
procedures beyond those specifically required by statute because
``unwarranted judicial examination of perceived procedural shortcomings
of a rulemaking proceeding can do nothing but seriously interfere with
that process prescribed by Congress.'' \39\ EPA followed the
[[Page 5071]]
procedures required by Congress in the CAA and EPA believes that no
additional proceedings are warranted.
---------------------------------------------------------------------------
\36\ See 42 U.S.C. 7607(d)(5).
\37\ See 5 U.S.C. 553(c); see also U.S. v. Allegheny-Ludlum
Steel Corp., 406 U.S. 742, 757 (1972).
\38\ See 42 U.S.C. 7607(d)(5); see also Anaconda Co. v.
Ruckelshaus, 482 F.2d 1301, 1306 (10th Cir. 1973).
\39\ Vermont Yankee Nuclear Power Corp. v. Natural Res. Def.
Council, Inc., 435 U.S. 519, 548 (1978).
---------------------------------------------------------------------------
Moreover, Congress specifically contemplated and rejected a cross-
examination requirement for public hearings in section 307.\40\ The
House bill contained an opportunity to cross-examine those who made
oral presentations at the public hearing. During Conference Committee,
this was deleted and replaced with a requirement that the rulemaking
record remain open for thirty days after public hearing to allow
interested parties to submit rebuttal and supplemental information.\41\
---------------------------------------------------------------------------
\40\ Kennecott Corp. v. EPA, 684 F.2d 1007, 1020 (D.C. Cir.
1982).
\41\ See H.R. Rep. No.95-564, 95th Cong. (1977).
---------------------------------------------------------------------------
The comment cites Goldberg v. Kelly, 397 U.S. 254, 262-63 (1970)
and argues that Basin Electric, like the welfare recipient in Goldberg,
has an especially strong claim to an evidentiary hearing prior to EPA's
final rulemaking because Basin Electric may be ``condemned to suffer
grievous loss.'' The comment fails to explain why the private interest
of Basin Electric here is identical to the Goldberg welfare recipient's
private interest in an evidentiary hearing before the termination of
welfare benefits. The comment also does not examine the factors set out
in Mathew v. Eldridge, 424 U.S. 319 (1976),\42\ for determining what
due process requires, and so does not provide any reason for EPA to
think that the procedures here were inadequate. In particular, the
comment provides no basis to think that EPA's procedures created a
serious ``risk of an erroneous deprivation'' of Basin Electric's
interest and that there would be any ``probable value'' to cross-
examination. With respect to the alleged errors referred to in the
comment, Basin Electric has made its arguments as to why they are
errors and EPA has responded why they are not. If Basin Electric thinks
EPA's responses are inadequate, then Basin Electric may seek judicial
review of EPA's action under section 307(b) of the Act. The risk of
erroneous deprivation appears small, and Basin Electric's comment gives
no reason to think otherwise. Basin Electric's comment also does not
identify any particular value to cross-examination in this context. As
the comment admits, the matters here are ones of technical judgment;
they are not (for example) eyewitness accounts that might benefit from
cross-examination.
---------------------------------------------------------------------------
\42\ ``[I]dentification of the specific dictates of due process
generally requires consideration of three distinct factors: First,
the private interest that will be affected by the official action;
second, the risk of an erroneous deprivation of such interest
through the procedures used, and the probable value, if any, of
additional or substitute procedural safeguards; and finally, the
Government's interest, including the function involved and the
fiscal and administrative burdens that the additional or substitute
procedural requirement would entail.'' Eldridge, 424 U.S. at 335.
---------------------------------------------------------------------------
EPA also notes that the comment fails to discuss ``the Government's
interest, including . . . the fiscal and administrative burdens'' that
cross-examination would entail. Eldridge alternatively identified this
third factor as ``the public interest.'' Eldridge, 424 U.S. at 347. In
considering the burdens imposed by a full adjudicatory hearing on the
Government and the public, the Tenth Circuit Court of Appeals stated
(albeit before Eldridge, so not in the context of applying the Eldridge
factors):
Unending procedure could be produced by an adjudicatory hearing.
This could bring about unending delay which would not only impede
but completely stifle congressional policy. We do not, of course,
condemn the trial court's concern for the rights of [the
petitioner]. Those rights are important and the court should be
sensitive to them, but those rights are not of such magnitude as to
overcome congressional policy and the rights of the remainder of the
community.
Anaconda Co. v. Ruckelshaus, 482 F.2d 1301, 1307 (10th Cir. 1973). The
comment gives EPA no reason to think otherwise.
With respect to the comment's invocation of the BiMetallic-Londoner
distinction between rulemaking and adjudication, it is not clear that
Londoner applies here, where the interests of many parties are at
stake. See Anaconda, 482 F.2d at 1306 (``The fact that Anaconda alone
is involved is not conclusive on the question as to whether the hearing
should be adjudicatory, for there are many other interested parties and
groups who are affected and are entitled to be heard. So the guidelines
enunciated by Mr. Justice Holmes in Bi-Metallic Investment Co. v. State
Board of Equalization are not applicable.'') (citation omitted). Even
if the distinction does apply, due process does not per se require a
full adjudicatory hearing. As the comment admits, what due process does
require is that a person ``have the right to support his allegations by
argument, however brief: and, if need be, by proof, however informal.''
Londoner v. City & Cnty. of Denver, 210 U.S. 373, 386 (1908). Thus the
``core of due process is the right to notice and a meaningful
opportunity to be heard.'' \43\ With respect to whether a full
evidentiary hearing is required, ``differences in the origin and
function of administrative agencies preclude wholesale transplantation
of the rules of procedure, trial, and review which have evolved from
the history and experience of courts. The judicial model of an
evidentiary hearing is neither a required, nor even the most effective,
method of decision making in all circumstances.'' Eldridge, 424 U.S. at
348 (citations and quotations omitted).
---------------------------------------------------------------------------
\43\ LaChance v. Erickson, 522 U.S. 262, 266 (1988).
---------------------------------------------------------------------------
EPA believes Basin Electric was afforded a meaningful opportunity
to be heard and present evidence to EPA in support of its position. EPA
notified the public of its proposed rule, held a public hearing, and
accepted public comments for a period of 60 days.\44\ In an effort to
provide a greater opportunity for public comment on the proposed rule,
EPA held two additional public hearings and extended the comment period
to 75 days, which goes beyond the procedures required by the CAA. \45\
Basin Electric submitted extensive comments prior to the first comment
deadline, participated in two public hearings, and submitted additional
comments during the extended public comment period.\46\ Basin Electric
took full advantage of its opportunity to be heard and was not denied
due process.
---------------------------------------------------------------------------
\44\ Implementation Plans; Approvals, Disapprovals and
Promulgations: Wyoming; Regional Haze State Implementation Plan;
Federal Implementation Plan for Regional Haze June 10, 2013 Docket
EPA-R08-OAR-2012-0026-0093.
\45\ Air Quality State Implementation Plans; Approvals,
Disapprovals and Promulgations: Wyoming; Regional Haze State
Implementation Plan; Federal Implementation Plan for Regional Haze;
Public Hearings Jul. 8, 2013 Docket EPA-R08-OAR-2012-0026-0098; see
42 U.S.C. 7607(d)(5).
\46\ Basin Electric Power Cooperative Comments, Aug. 6, 2013
Docket EPA-R08-OAR-2012-0026-0058; Public Comment from Basin
Electric Email Aug. 9, 2013 Docket EPA-R08-OAR-2012-0026-0148;
Transcript from July 26, 2013 Hearings in Casper, Wyoming Aug. 8,
2013 Docket EPA-R08-OAR-2012-0026-0108 pp. 48-83; Transcript from
June 24, 2013 Hearings in Cheyenne, Wyoming Aug. 15, 2013 Docket
EPA-R08-OAR-2012-0026-0100 pp. 62-67; Additional Public Comment from
Basin Electric Laramie River Station BART CALPUFF Modeling Analysis
Aug. 26, 2013 Docket EPA-R08-OAR-2012-0026-0227.
---------------------------------------------------------------------------
Comment: Section 169A requires the State to take into consideration
five different factors when making its BART determination. 43 U.S.C.
7491(g)(2). But these factors ``were meant to be considered together''
to arrive at a single judgment committed to the State: A BART emission
limit. American Corn Growers, 291 F.3d at 6. Moreover, only Wyoming--
not EPA--is entitled to determine the weight and significance to assign
costs, feasibility, and visibility improvements. 70 FR 39123 (``The
State makes a BART determination based on the estimates available for
each criterion, and as the CAA does not
[[Page 5072]]
specify how the State should take these factors into account, the
States are free to determine the weight and significance to be assigned
to each factor.''); see also 40 CFR Part 51, App. Y, Section IV.D.5.
By applying a different assessment of costs and visibility than
those employed by Wyoming in its BART determination, and assuming that
these assessments mandate a different BART outcome, EPA's proposed FIP
rejects the State's determinations on cost, feasibility, and visibility
improvement without considering whether, taken together, the five
statutory factors would compel a different result than the one reached
by Wyoming. The net result is a decision imposing a different BART
choice than that selected by the State by splitting the statutory
factors and giving them separate and independent determinative
significance--the same legal error EPA made in American Corn Growers.
The ``splitting of the statutory factors is consistent with neither the
text nor the structure of the statute.'' 291 F.3d at 6.
Wyoming must therefore be afforded an opportunity to reconsider its
BART determination before EPA imposes a FIP. This is necessary to
preserve State primacy in the BART determination. States ``determine
what is too costly (and what is not) for a particular source.'' Am.
Corn Growers, 291 F.3d at 6-7. The actual BART determination flows not
from any one of the statutory factors, but instead from consideration
of all of them together. That is why it is erroneous for EPA to impose
its own BART choice without explaining how it reached that choice upon
consideration of all five statutory factors. If EPA acts to correct
alleged errors in the State's cost assessment or visibility modeling,
EPA must remand the statutory evaluation back to the State. Section
110(c) contemplates that States should be given an opportunity to
correct any ``deficiencies,'' and this statutory opportunity should not
be taken from the State as a result of self-imposed consent decree
deadlines. Doing so destroys State primacy in the BART determination.
It also results in a BART determination from EPA that is not
informed and explained by an independent assessment of the five
statutory factors. EPA's failure to remand the BART determination back
to the State therefore results in neither the State nor EPA making a
BART assessment that considers all of the statutory factors together.
While Basin Electric acknowledges that the Tenth Circuit Court of
Appeals recently reached a different conclusion in Oklahoma v. EPA, 723
F.3d 1201 (10th Cir. 2013), that case is not yet final and that Court
was not presented with, and did not consider, the fundamental problem
associated with EPA's effort to make one of the five statutory factors
outcome determinative. EPA cannot cause an outcome in which no agency
has actually complied with the statute, which is what happens when EPA
simultaneously disapproves the State's BART assessment on one or two
statutory factors and then imposes a different BART assessment based
upon cost and visibility factors combined with the State's prior
consideration of the other factors, as EPA does here. This is not a
procedural error, but rather an error that results in no agency--
neither the State nor EPA--actually complying with the statute by
considering all five statutory factors together before arriving at a
BART emission limit.
Response: EPA does not agree with this comment. The RHR and the
BART Guidelines allow the reviewing authority (State, Tribe, or EPA)
the discretion to determine how to weigh and in what order to evaluate
the statutory factors (cost of compliance, the energy and non-air
quality environmental impacts of compliance, any existing pollution
control technology in use at the source, the remaining useful life of
the source, and the degree of improvement in visibility which may
reasonably be anticipated to result from the use of such technology),
as long as the reviewing authority justifies its selection of the
``best'' level of control and explains the CAA factors that led the
reviewing authority to choose that option over other control
levels.\47\ In this action, having disapproved the State's BART
determinations for NOX at five units, ``all of the rights
and duties that would otherwise fall to the State accrue instead to
EPA.'' \48\ This includes a significant degree of discretion in
deciding how to weigh the five factors, so long as that weighing is
accompanied by reasoned explanation for adopting the technology
selected as BART, based on the five factors, and in accordance with the
BART Guidelines. EPA has provided a detailed explanation of our BART
evaluation process and five-factor analyses in our proposal, and
elsewhere in this final notice. We have weighed the potential energy
and non-air environmental quality impacts of the various control
options along with the other statutory factors in our BART analyses. We
have not, as the commenter surmises, approved the State's assessment of
certain factors and disapproved the assessment of others, replacing
just the factors we have disapproved. Instead, for those NOX
BART determinations we are disapproving, we have disapproved them in
their entirety. Then EPA independently assessed and weighed the five
factors. That we adopted the State's assessment of certain factors as
our own does not change this. Thus the split in authority that the
commenter suggests simply has not occurred.
---------------------------------------------------------------------------
\47\ See BART Guidelines, 40 CFR Part 51, appendix Y, section
IV.E.2.
\48\ Central Arizona Water Conservation Dist. v. EPA, 990 F.2d
1531, 1541 (9th Cir. 1993).
---------------------------------------------------------------------------
We also disagree that our proposal is inconsistent with the
American Corn Growers decision. In American Corn Growers, the
petitioners challenged the original RHR because, among other things,
the RHR treated one of the five statutory factors differently than the
others by requiring states to consider the degree of visibility
improvement from imposing BART on a group of sources rather than on a
source-specific basis.\49\ The court concluded that such a requirement
could force states to apply BART controls at sources without evidence
that the individual sources contributed to visibility impairment at a
Class I area, which encroached on states' primary authority under the
regional haze provisions to determine which individual sources are
subject to BART and what BART controls are appropriate for each
source.\50\ Therefore, the court vacated the visibility improvement
part of the original RHR as contrary to the statute.\51\ Contrary to
some commenters' suggestions, however, the American Corn Growers
decision did not address EPA's authority to reject a state's BART
determinations for failure to conform to the CAA, the RHR, or the BART
Guidelines.
---------------------------------------------------------------------------
\49\ 291 F.3d at 5-9.
\50\ Id. at 7-8.
\51\ EPA revised the RHR to address the court's decision in
American Corn Growers at the same time as we promulgated the BART
Guidelines. 70 FR 39104 (July 6, 2005). The revised RHR and the
Guidelines were upheld by the D.C. Circuit in Utility Air Regulatory
Group v. EPA, 471 F.3d 1333 (D.C. Cir. 2006).
---------------------------------------------------------------------------
Finally, as explained elsewhere in this final rule, we have the
authority to promulgate a FIP concurrently with a disapproval action.
Comment: EPA's FIP is subject to APA review. Accordingly, it cannot
withstand judicial scrutiny if it is arbitrary, capricious, an abuse of
discretion, or not in accordance with the law. See 5 U.S.C. 706(2)(A);
Olenhouse, 42 F.3d at 1574. More generally, a court will set it aside
``if the agency relied on factors which Congress has not intended for
it to consider, entirely failed to
[[Page 5073]]
consider an important aspect of the problem, offered an explanation for
its decision that runs counter to the evidence before the agency, or is
so implausible that it could not be ascribed to a difference in view or
the product of agency expertise.'' State Farm, 463 U.S. at 43.
A court reviewing agency action under the APA must ``ascertain
whether the agency examined the relevant data and articulated a
rational connection between the facts found and the decision made.''
Olenhouse, 42 F.3d at 1574 (citing State Farm, 463 U.S. at 43)
(footnote omitted). A reviewing court also must review the agency's
explanation to ``determine whether the agency considered all relevant
factors and whether there has been a clear error of judgment.'' Id.
(citing, inter alia, Citizens to Preserve Overton Park, Inc. v. Volpe,
401 U.S. 402, 416 (1971)). The court ```should not attempt itself to
make up for . . . deficiencies''' in the agency's reasoning and ``may
not supply a reasoned basis for the agency's action that the agency
itself has not given.'' Id. at 1574-75 (quoting State Farm, 463 U.S. at
43) (emphasis removed).
As a result, ```an agency's action must be upheld, if at all, on
the basis articulated by the agency itself,'' and ``the grounds upon
which the agency acted must be clearly disclosed in, and sustained by,
the record.'' Id. at 1575 (quoting State Farm, 463 U.S. at 50). In its
decision, ``[t]he agency must make plain its course of inquiry, its
analysis and its reasoning.'' Id. Moreover, its action must be
``supported by the facts in the record.'' Id. This means the action
must be supported by ``substantial evidence,'' i.e., ```enough to
justify, if the trial were to a jury, a refusal to direct a verdict
when the conclusion to be drawn is one of fact.''' Id. (citation
omitted). In addition to providing a basis for invalidating the agency
action, an agency's failure to fully explain and support its reasoning
warrants a court's grant of less deference to the agency's decisions.
See, e.g., Achernar Broad. Co. v. FCC, 62 F.3d 1441, 1447 (D.C. Cir.
1995) (``no deference is due when the agency has stopped shy of
carefully considering the disputed facts''); NLRB v. P*I*E Nationwide,
Inc., 923 F.2d 506, 518 n.16 (7th Cir. 1991) (``deference given to an
agency is not granted freely, it is purchased; the agency must exercise
its touted expertise and ``explain the rationale and factual basis for
its decision'') (citation omitted).
Although a court generally will defer to an agency's experts when
the agency acts within its area of expertise, a court will not do so
and will invalidate the agency's action where its expert's decisions
were arbitrary and capricious. See, e.g., Garvey, 256 F.3d at 1036
(agencies can rely on their own experts only ``so long as their
decisions are not arbitrary and capricious'') (citation omitted). See
also NetCoalition v. SEC, 615 F.3d 525, 539 (D.C. Cir. 2010) (``[W]e do
not defer to the agency's conclusory or unsupported suppositions.'')
(citation omitted); Brower v. Evans, 257 F.3d 1058, 1067 (9th Cir.
2001) (``The deference accorded to an agency's scientific or technical
expertise is not unlimited. The presumption of agency expertise can be
rebutted when its decisions, while relying on scientific expertise, are
not reasoned.'') (citation omitted); Nat. Resources Defense Council,
725 F.2d at 768, 771 (the court owed EPA no deference where the agency
``complete[ly] fail[ed] to consider the criteria that should inform
[its decision]''). Similarly, an agency can rely on a model ``only so
long as it `explains the assumptions and methodology used in preparing
the model' and `provides a complete analytical defense' should the
model be challenged.'' Appalachian Power Co. v. EPA, 249 F.3d 1032,
1052 (D.C. Cir. 2001) (citation and brackets omitted). See also Sierra
Club v. Costle, 657 F.2d 298, 333 (D.C. Cir. 1981) (although computer
modeling undoubtedly ``is a useful and often essential tool,'' an
``agency must sufficiently explain the assumptions and methodology used
in preparing the model'' and must ``provide a complete analytic defense
of its model (and) respond to each objection with a reasoned
presentation'') (internal quotation marks omitted), rev'd on other
grounds, 463 U.S. 680 (1983); id. (there must be ``a rational
connection between the factual inputs, modeling assumptions, modeling
results and conclusions drawn from these results''). Here, in
promulgating its FIP, EPA was required to do the same thing Wyoming
did: determine BART by ``tak[ing] into consideration'' the five
statutory factors, including the costs of compliance, the energy and
non-air quality environmental impacts of compliance, any existing
pollution control technology in use at the source, the remaining useful
life of the source, and the degree of improvement in visibility that
may reasonably be anticipated to result from the use of the technology.
CAA Section 169A(g)(2), 42 U.S.C. 7491(g)(2). As the D.C. Circuit
explained in American Corn Growers, ``the factors were meant to be
considered together'' in determining BART, as ``[t]he language of
section 169A(g)(2) can be read in no other way.'' 291 F.3d at 6.
Accordingly, in order to comply with the CAA and withstand APA
review, EPA must fully explain how it assessed and weighed the five
BART factors together, and it must support that explanation with record
facts. EPA has failed to do so. Additionally, the same regulations EPA
promulgates for state BART determinations must also apply to BART
determinations made by EPA. See CAA Section 169A(b)(2)(A), 42 U.S.C.
7491(b)(2)(A). Indeed, it would be arbitrary and capricious for EPA to
require a state to follow certain specific guidelines in making a BART
determination, yet to not itself follow those same guidelines in making
that same determination after taking it out of the state's hands.
Moreover, EPA has suggested that the BART Guidelines and Cost Manual
are mandatory provisions that must be followed in order to comply with
the CAA.
Response: We disagree with this comment. As detailed elsewhere in
this document and documented in the supporting record, EPA applied the
BART statutory factors and BART Guidelines to each and every BART unit
that is covered under this rulemaking; fully considered all significant
comments submitted on the proposed notices and incorporated those
comments as appropriate; provided basis for the decisions; applied
models that are specified in the BART Guidelines (thus, the opportunity
for commenters to challenge the specified models has long passed);
developed and provided detailed explanations regarding EPA's model
inputs and settings; and rationally applied the modeling results to the
final determinations in applying the BART and reasonable progress
factors. The comment does not identify any deficiency in any portion of
this.
Comment: Wyoming developed a SIP that established reasonable
progress toward meeting the national goal for regional haze as required
under the CAA Section 169A(a)(1). EPA's establishment of a 2064 goal
and glide path requires incremental visibility improvement for
successive planning periods. EPA also clearly explains in these
requirements that the glide path and 2064 target date are not binding.
This provides considerable latitude to the individual states that are
responsible to develop a regional haze SIP that makes reasonable
progress in a way that works to achieve the visibility goals over time.
The State developed and submitted a plan that would make
substantial progress in reducing haze at the affected Class I areas.
The State followed the process in the EPA's Regional Haze
[[Page 5074]]
Guidelines, yet because it came to a different conclusion than EPA, the
plan was rejected and replaced with EPA's FIP.
By rejecting the State's reasonable approach, EPA has ignored its
own requirements and guidance. EPA's issuance of a FIP not only ignores
the flexibility and authority granted the State, it also ignores EPA's
guidance for establishing reasonable control requirements.
Response: EPA disagrees with this comment. While the RHR does not
require states to achieve the URP, when a state's selected RPGs do not
meet the URP, the state must demonstrate, based on the four reasonable
progress factors, that meeting the URP is not reasonable and that the
selected RPGs are reasonable. 40 CFR 51.308(d)(1)(ii). As discussed
elsewhere, the State did not appropriately consider the four reasonable
progress factors for Dave Johnston Units 1 and 2, and to the extent
that the State relied on its BART determinations to show reasonable
progress for those sources, we have disapproved some of those BART
determinations. While the comment states that EPA ``ignored its own
requirements and guidance,'' the comment does not cite any particular
requirement that EPA purportedly violated.
Comment: The EPA proposal is deficient in large measure because the
EPA has identified what it views as deficiencies in the Wyoming SIP
and, rather than ordering reconsideration of all relevant factors with
improved data, has created a FIP that suffers from analytical errors
and arrogates the EPA's role in development and review of SIPs. If the
EPA was convinced Wyoming's cost estimates were in error, it should
have directed corrections, rather than substituting other flawed data
and its own judgment. Indeed, it is apparent the EPA is not committed
to maintaining the CAA's deference to states' authority to formulate
workable haze plans. Otherwise, the EPA would have required Wyoming to
correct perceived cost estimate errors and subsequently reevaluate BART
factors. The EPA instead, substituted its own errors and performed its
own evaluation in pursuit of its own goals.
Another commenter argued that EPA should not impose a FIP until it
has issued a final rule disapproving the Wyoming regional haze SIP. 42
U.S.C. 7410(c)(1)(B). EPA should first conduct a rulemaking and take
public comment on the Wyoming regional haze SIP submission, issue its
determination on the regional haze SIP, and then seek input from the
State. (See 42 U.S.C. 7410(c)(1)(B); see also 42 U.S.C. 7607(d)(B)
(rulemaking provisions apply to ``the promulgation or revision of an
implementation plan by the Administrator under section 7410(c)'')
Otherwise, EPA removes the State from its assigned role as the one
determining BART.
The facts here illustrate this problem. EPA initially agreed with
Wyoming's BART determinations for Naughton Units 1 and 2, and Dave
Johnston Unit 3. EPA then reversed itself, supposedly on the basis of
new cost and visibility information. Without offering Wyoming any
chance to review the new information and issue a new BART
determination, EPA disapproved Wyoming's BART determination for these
units, and instituted new BART determinations for these units through a
regional haze FIP. EPA's failure to provide Wyoming an opportunity to
review this new information, and address it through a revised BART
determination, violates the applicable CAA statutes.
The CAA defines a FIP as a plan (or portion thereof) promulgated by
the (EPA) Administrator to fill all or a portion of a gap or otherwise
correct all or a portion of an inadequacy in a SIP. 42 U.S.C. 7602(y).
Until EPA first assesses the Wyoming regional haze SIP, develops a
proposed rule to approve or disapprove the Wyoming regional haze SIP,
solicits and receives public comment on that proposed rule, considers
the comments and information, and takes final action on whether (and to
what extent) to approve the Wyoming SIP, EPA cannot know whether there
is a ``gap'' in the Wyoming regional haze SIP that needs to be filled
or whether (and to what extent) there is an ``inadequacy'' in the
Wyoming regional haze SIP that needs to be corrected. Id. Moreover,
EPA's failure to obtain public comments prior to proposing a regional
haze FIP deprives Wyoming of an opportunity to correct any
``deficiencies'' identified by EPA. Here, where EPA claims to have
obtained new cost and visibility information but did not allow Wyoming
an opportunity to review and act on the new information, EPA's final
determination regarding the Wyoming regional haze SIP ignores the
State's authority under the CAA (including the regulatory programs
implicated by CAA Section169A) to design and implement plans to control
air pollution control within its borders. (See 42 U.S.C. 7401(a)(3).)
Therefore, EPA illegally seeks to impose its regional haze FIP and
should withdraw the same.
Earlier comments argued that EPA cannot impose a regional haze FIP
until it has issued a final rule disapproving Wyoming's regional haze
SIP. 42 U.S.C. 7410(c)(1)(B) mandates that disapproval of all or part
of a SIP is a prerequisite to promulgation of a FIP. EPA must first
conduct a rulemaking and take public comment on Wyoming's regional haze
SIP submission, issue its determination on the regional haze SIP, and
then proceed, or not, with promulgation of a regional haze FIP. (See 42
U.S.C. 7410(c)(1)(B); see also 42 U.S.C. 7607(d)(B) (rulemaking
provisions apply to ``the promulgation or revision of an implementation
plan by the Administrator under section 7410(c)'')
Response: We disagree with this comment. We have the authority to
promulgate a FIP concurrently with a disapproval action. Nowhere in the
CAA is there language that limits EPA's authority to simultaneously
propose a FIP and propose disapproval of a state's SIP where there has
been a prior finding of a failure to submit. This timing for FIP
promulgation is authorized under CAA section 110(c)(1). As has been
noted in past FIP promulgation actions, the language of CAA section
110(c)(1), by its terms, establishes a two-year period within which we
must promulgate the FIP, and provides no further constraints on timing.
See, e.g., 76 FR 25178, at 25202. Wyoming failed to submit the 40 CFR
51.309(g) plan elements by December 17, 2007, as required under the CAA
and our implementing regulations. Two years later, Wyoming still had
not submitted these required plan elements. When we made the finding in
2009 that Wyoming had failed to submit these regional haze SIP elements
(see 74 FR 2392), that created an obligation for us to promulgate a FIP
by January 2011. We are exercising our discretion to promulgate the FIP
concurrently with our disapproval action because of the applicable
statutory deadlines requiring us at this time to promulgate regional
haze BART determinations to the extent Wyoming's BART determinations
are not approvable. In these concurrent SIP/FIP actions, if comments or
other information cause us to reconsider portions of our proposed
disapproval, and instead approve additional portions of Wyoming's SIP,
we can readily adjust our FIP accordingly by not finalizing the FIP
portions that are no longer needed, as, indeed we are doing in this
case. Thus, the supposed procedural problem the comment identifies
simply does not exist.
With respect to the argument that the CAA requires EPA, before
promulgating a FIP, to give additional opportunities to Wyoming to
address the deficiencies that EPA has identified, in fact the
[[Page 5075]]
opposite is true. Under section 110(c)(1) of the CAA, EPA must
promulgate a FIP within 2 years of a finding of failure to submit a
required SIP submittal. As explained above, the requirement for a FIP
promulgation in today's action was triggered by a finding published on
January 15, 2009 (74 FR 2392), that Wyoming (among other states) had
failed to make a submittal to address the requirements of 40 CFR
51.309(g). Thus, EPA had an obligation to promulgate a FIP for the
requirements of 40 CFR 51.309(g) by January 15, 2011, unless the State
submitted and EPA approved a SIP addressing the deficiency. Although we
are approving portions of Wyoming's SIP that meet the requirements of
51.309(g), we are disapproving other portions and, therefore, are still
under an obligation to promulgate a FIP for those portions. In
considering a similar argument to that made by the commenter, the Tenth
Circuit Court of Appeals has stated:
Once the EPA issued findings that Oklahoma failed to submit the
required SIP under the Regional Haze Rule, the EPA had an obligation
to promulgate a FIP. The statute itself makes clear that the mere
filing of a SIP by Oklahoma does not relieve the EPA of its duty.
And the petitioners do not point to any language that requires the
EPA to delay its promulgation of a FIP until it rules on a proposed
SIP. As the EPA points out, such a rule would essentially nullify
any time limits the EPA placed on states. States could forestall the
promulgation of a FIP by submitting one inadequate SIP after
another.
Oklahoma v. EPA, 723 F.3d 1201, 1223 (10th Cir. 2013).
Finally, as explained elsewhere, under the FIP, the State retains
its authority to submit future regional haze SIPs consistent with CAA
and RHR requirements; which may result in the modification or
withdrawal of the FIP.
Comment: The CAA and the RHR provide substantial discretion to
states to determine how best to make reasonable progress toward
achieving natural visibility conditions in designated areas. Reasonable
progress--the touchstone of the regional haze program--is a flexible
benchmark. See 42 U.S.C. 7491(g)(1). In recognition of this overarching
flexibility and the need to account for local conditions, Congress
directed EPA to allow states discretion in how they determine the BART
for improving visibility. Id. Section 7491(b)(2)(A); Am. Corn Grower
Ass'n v. EPA, 291 F.3d 1, 8 (D.C. Cir. 2002) (``Congress intended the
states to decide which sources impair visibility and what BART controls
should apply to those source.''); see also 40 CFR 51.308(e)(1)(ii)(A).
Against this backdrop of state discretion, the CAA requires SIPs to
include: generally, ``such emission limits, schedules of compliance and
other measures as may be necessary to make reasonable progress toward
meeting the national goal [of natural visibility conditions in national
parks and wilderness areas],'' 42 U.S.C. 7491(b)(2); ``a long-term (ten
to fifteen years) strategy for making reasonable progress toward
meeting the national goal,'' id. Section 7491(b)(2)(B); and more
specifically, a plan for particular sources to ``procure, install, and
operate, as expeditiously as practicable (and maintain thereafter) the
best available retrofit technology,'' id. Section 7491(b)(2)(A).
Response: The CAA gives states substantial but not unfettered
discretion in determining BART and reasonable progress. We have already
largely addressed the assertions in this comment in our responses to
comments on our legal authority. Furthermore, as a hypothetical
example, EPA would not defer to a state determination that the
remaining useful life of a source is one year if relevant evidence
indicates the remaining useful life is 20 years. Limits on state
discretion are inherent in the CAA and our regulations; otherwise,
states would be free to reach decisions that are arbitrary and
capricious or inconsistent with the purpose behind the CAA and EPA's
regulations. As we have stated, while we have approved much of
Wyoming's SIP submittal, those elements which we have disapproved and
for which we are finalizing a FIP thwart the goals stated by Congress
in CAA section 169A and underlying the RHR. Those statutory and
regulatory provisions cannot be simply dismissed under the mantle of
state discretion.
Comment: On May 28, 2009, Wyoming published its BART application
analyses for the PacifiCorp and Basin Electric facilities subject to
BART. Wyoming solicited public comments on the analyses and to that end
held public hearings. EPA commented on Wyoming's analyses on August 3,
2009. EPA was fully aware of Wyoming's BART proposals, but, at that
time EPA gave no indication that Wyoming's BART proposals violated the
CAA or were unreasonable.
Both PacifiCorp and Basin Electric ultimately challenged Wyoming's
BART determinations before the Wyoming Environmental Quality Council.
See Appeal & Pet. for Review of BART Permits, In re BART Permit Nos.
MD-6040 and MD-6042, No. 10-2801 (Wyo. Envtl. Quality Council Feb. 26,
2010) (PacifiCorp Petition); Appeal & Pet. for Review, In re Basin
Electric Power Coop., No. 10-2802 (Wyo. Envtl. Quality Council March 8,
2010) (Basin Petition). The Environmental Quality Council is an
independent administrative body charged with adjudicating issues
arising under Wyoming environmental law, including BART determinations.
See Wyo. Stat. Ann. Sections 35-11-111, 112.
Both Basin Electric and PacifiCorp served their petitions for
review on EPA Region 8. EPA was again fully apprised of Wyoming's final
BART decisions, as well as the appeals of those decisions. EPA elected
not to participate in those proceedings, and, again, provided no
indication that EPA viewed Wyoming's BART decisions as invalid.
After filing motions for summary judgment, PacifiCorp and Basin
Electric both ultimately settled their litigation with the State. The
Environmental Quality Council approved the settlements after providing
an opportunity for public comment. EPA did not comment on the
settlement agreements. Because no aggrieved person appealed the
Council's decision approving the settlements, the permit decisions
became final by operation of law. Wyoming therefore incorporated the
BART permits into its SIP.
Years later, when EPA proposed action on Wyoming's SIP, EPA raised
for the first time its disagreement with the BART decisions that
PacifiCorp, Basin, and Wyoming had already litigated to conclusion.
Because EPA had the opportunity to participate in the litigation and
elected not to, EPA is now precluded from collaterally attacking those
permit decisions. See, e.g., ADEC, 540 U.S. at 490 n.14. To conclude
otherwise--that EPA can forgo participation in state adjudications only
to later attack the conclusions of those state processes--is to give
EPA the power to nullify state court judgments. Id. at 1015 (Kennedy,
J., dissenting). Congress did not intend to so empower EPA to turn
federalism on its head through the regional haze program.
Response: EPA disagrees with this comment. First, the comment does
not identify any way in which EPA is precluded from exercising its
authority and duty under the CAA to ensure that SIP submittals meet the
requirements of the Act. The notion that a state BART determination is
insulated from the requirements of the Act merely because the state has
an administrative appeal process is contrary to the Act itself as well
as the Supremacy Clause of the U.S. Constitution. Had Congress wanted
to require EPA to participate in state rulemaking or permit processes,
Congress would have explicitly stated this in the Act. With respect to
the
[[Page 5076]]
ADEC dissent, it is just that, a dissent. Even if the dissent were
somehow relevant, EPA is not nullifying a state court judgment. The
Wyoming Environmental Quality Council is not within the State judicial
branch. It is an executive agency. The members are appointed by the
Governor and serve at the Governor's pleasure. See Wyo. Stat. Ann.
Section 35-11-111(a) (``Council members shall be appointed by the
governor with the advice and consent of the senate. The governor may
remove any council member as provided in W.S. 9-1-202.''); Section 9-1-
202(a) (``[A]ny person may be removed by the governor, at the
governor's pleasure, if appointed by the governor to serve . . . as a
member of a state board or commission.'').
Furthermore, EPA's comments to Wyoming on its proposed SIP and BART
permits, which are in the docket for this action, emphasized that we
would only come to a final conclusion regarding the adequacy of
Wyoming's BART determinations when we acted on Wyoming's regional haze
SIP revision, through public notice and comment rulemaking. While we
may have been silent on some issues, silence from the EPA does not
signify implicit approval. Any lack of participation by the EPA in the
state administrative appeal proceeding or failure to register an
objection to the settlement agreement is not an indication that a
state's proposed BART determination will be approved following its
submittal as part of a larger regional haze SIP, as discussed in
greater detail elsewhere in this document. Wyoming is required to adopt
a final BART determination as part of its regional haze SIP. As
explained elsewhere in this document, once a state submits a SIP to the
EPA, we are authorized to approve, partially approve, or disapprove the
SIP, and we have the duty to assure that the SIP submittal complies
with the requirements of the Act. The statutory scheme explicitly
provides for this.
Alaska Depart of Environmental Conservation v. Environmental
Protection Agency, 540 U.S. 461 (2004) concerned EPA's response to
ADEC's issuance of a permit to a mine that provided, as BACT,
unreasonably low NOX controls. Accordingly, EPA issued three
orders prohibiting ADEC from granting the permit unless it
satisfactorily documented its reasoning behind its BACT determination.
The Ninth Circuit held the three orders were a proper exercise of EPA's
authority and discretion. The Supreme Court affirmed. EPA agrees with
the commenter that EPA made representations to the Court stating the
need to accord ``appropriate deference'' to states' determinations. EPA
also agrees that we made the representation that we have never asserted
our authority to override a state-court judgment, and therefore, the
fear that EPA will threaten state courts' independence is unfounded.
While EPA did make these representations, these representations are
not inconsistent with EPA's decision to disapprove Wyoming's BART
determination for Laramie River Station. As explained above, we are not
overriding a state-court judgment. Furthermore, the notion that a state
administrative appeal process can insulate a BART determination from
federal requirements itself ``turns federalism on its head.'' See U.S.
Constitution, Art. VI, cl. 2 (supremacy clause).
In this instance, some of Wyoming's BART determinations were
unreasonable in terms of cost effectiveness and other factors as
detailed elsewhere in this document (detailed descriptions of the cost
assumption are described in the comments specific to the units
elsewhere in this document).\52\ Finding Wyoming's BART determinations
to be unreasonable is a ``restrained and moderate'' use of EPA's
statutory authority. See 540 U.S. at n.14. Following EPA's issuance of
orders to ADEC for failing to establish a reasonable BACT, the Court
noted, ``Only when a state agency's BACT determination is `not based on
a reasoned analysis' . . . may EPA step in to ensure that the statutory
requirements are honored.'' 540 U.S. 461, 490. In the case of Wyoming's
BART determinations, EPA adhered to a similar role. Upon finding some
of Wyoming's BART determinations unreasonable, EPA disapproved those
determinations and proposed an alternative standard.
---------------------------------------------------------------------------
\52\ As explained elsewhere in this document, EPA has accepted
some of the costs submitted in response to the proposed notice
developed for Basin Electric, but not others.
---------------------------------------------------------------------------
EPA continues to acknowledge the importance of significant
deference to state authorities regarding their BART determinations
since they are in the best position to make these determinations given
their close familiarity with the unique characteristics of their
particular area. This structure encourages cooperative federalism, a
principle that underlies the CAA. However, this ``initial
responsibility'' does not permit the state to make unreasonable BART
determinations. See 540 U.S. at 464. EPA is not using its authority to
disapprove part of a state's SIP as a way to override legitimate
administrative litigation reached under state law. Rather, we are
enforcing a requirement of the CAA concerning anthropogenic impairment
of visibility by ensuring that reasonable BART controls are considered.
State adjudicative processes are not threatened because states are free
to use these processes to reach their own BART determination, provided
that this determination is reasonable and consistent with the CAA.
Comment: Nowhere does the Act command national consistency in BART
cost estimates and, to the contrary, by allowing states to make
individualized BART determinations, Congress demonstrated that
consistency was not intended to be a component of the regional haze
program, save for the uniform objective of attaining natural visibility
conditions. The commenter indicated that the RHR takes the same
approach, allowing states wide discretion to conduct BART analyses, and
that the BART Guidelines encourage states to take into account site-
specific conditions that impact costs. In light of these authorities,
the commenter believes that the EPA cannot disapprove the State's cost
analyses simply because they do not fit within the EPA's preferred
vision of national uniformity.
Another comment argued that EPA claimed that the State failed to
follow the CCM, and the EPA supported this claim by quoting the CCM as
saying that the EPA prefers consistency in control cost estimates (78
FR 34749). The CAA, the RHR, the BART Guidelines, and the fact that
different sources have vastly different designs belie the EPA's
preference for ``consistency.'' Nowhere does the Act command national
consistency in BART cost estimates and, to the contrary, by allowing
states to make individualized BART determinations, Congress
demonstrated that consistency was not intended to be a component of the
regional haze program, save for the uniform objective of attaining
natural visibility conditions. The commenter indicated that the RHR
takes the same approach, allowing states wide discretion to conduct
BART analyses, and that the BART Guidelines encourage states to take
into account site-specific conditions that impact costs. In light of
these authorities, the commenter believes that the EPA cannot
disapprove the State's cost analyses simply because they do not fit
within the EPA's preferred vision of national uniformity.
Response: As we explain in our response to other comments in the
legal issue section, we have authority to assess the reasonableness of
a state's
[[Page 5077]]
analysis of costs; and a state's discretion must be reasonably
exercised in compliance with the applicable requirements. While we
agree that site-specific challenges must be identified and factored
into the cost effectiveness analysis, the SIP elements disapproved
elsewhere in this document items are not ``site-specific conditions,''
but rather use of the wrong costing methodology and improper
categorization of costs, as well as other issues. An erroneous analysis
of costs, whether due to methodological or to data flaws, prevents a
state from conducting a meaningful consideration of the cost of
compliance factor. North Dakota v. U.S. EPA, 730 F.3d 750, 761 (8th
Cir. 2013).
EPA is not relegated to a ministerial role. Id. We have not
replaced cost estimates, modeling analyses and other SIP elements
submitted by the State solely for the purpose of ensuring consistency
across states. When a state or source puts forward costs estimates that
are atypical, it is reasonable for us to scrutinize such estimates more
closely to determine whether they are reasonable or inflated. Also,
given that the assessment of costs is necessarily a comparative
analysis and one marker of reasonableness, it is reasonable to insist
that certain standardized and accepted costing practices be followed
absent unique circumstances. Such consistency is particularly relevant
for BART determinations at fossil-fuel fired power plants having a
capacity in excess of 750 MW, which must be made pursuant to the BART
Guidelines.\53\ To the extent a BART determination for such a power
plant is plainly inconsistent with EPA-approved determinations for
similar sources, it is more likely to be inconsistent with the RHR and
the BART Guidelines and therefore to warrant greater scrutiny for
compliance with the applicable requirements.
---------------------------------------------------------------------------
\53\ CAA section 169A(b) and 40 CFR 51.308(e)(1)(ii)(B).
---------------------------------------------------------------------------
Comment: Basin Electric submits with these comments an updated cost
estimate for SNCR and SCR emission controls at Laramie River Station.
That report states that in Sergeant & Lundy's opinion SNCR would likely
achieve a 48% reduction from EPA's input emission rate. However, when
it made its BART determination the State did not have the benefit of
this report and made its judgment based on the best information
available at the time. EPA, in its August 3, 2009 comments on Wyoming's
BART permit for Laramie River Station, stated that it estimated that
``SNCR can reduce NOX by 40%-50% for most large boilers (EPA
Air Pollutions Control Cost Manual, 2002, Sixth ed., EPA-452-02-001.
Section 4.2, Chapter 1, pg. 1-3.).'' States are entitled to rely on
information available at the time they make BART determinations, and
EPA may not disapprove a state's BART based on information that becomes
available later. This principle seems particularly appropriate when at
the time EPA itself asserts the bona fides of information similar to
that relied upon by the State.
Response: We disagree with this comment. EPA is required to take
new information submitted as part of this rulemaking into
consideration. Indeed, EPA has taken into consideration the updated
cost estimate information submitted by Basin Electric for SNCR and SCR
at Laramie River Station, which was not available to Wyoming. See
Sierra Club v. EPA, 671 F.3d 955, 967 (9th Cir. 2012) (``if new
information indicates to EPA that an existing SIP or SIP awaiting
approval is inaccurate or not current, then, viewing air quality and
scope of emissions with public interest in mind, EPA should properly
evaluate the new information and may not simply ignore it without
reasoned explanation of its choice''); see also 42 USC 7607(d)(6)(B)
(``The promulgated rule shall also be accompanied by a response to each
of the significant comments, criticisms, and new data submitted . . .
during the comment period.'') (emphasis added). Thus, EPA is required,
at a minimum, to take new information into account during the SIP
approval process and, if necessary, alter its final decision
accordingly. As explained in detail elsewhere, section 307(d) of the
Act explicitly provides for the consideration of information developed
after the proposed rule is published.
EPA considered this new cost information and the assessment of our
evaluation regarding this information appears elsewhere in this
document.
Comment: EPA is again overstepping its role in this process.
Wyoming completed its BART analysis in 2009, more than three years ago,
and it would have been impossible to incorporate the alleged urea price
increases in that analysis. Simply put, Wyoming's BART determination is
hardly arbitrary and capricious simply because it failed to take into
account alleged urea price increases some three years after Wyoming
completed its BART analysis. Wyoming did precisely what the Guidelines
instruct: made a BART determination based on information available
before the close of its public comment period. 40 CFR Part 51, App. Y.,
Section IV(D)(2)(3). To disapprove Wyoming's cost analysis based on
information that was not available to the State would be to employ a
``gotcha'' approach that runs contrary to EPA's own regulations and
counter to EPA's commitment to do its job fairly and objectively. If
the urea issue is truly material, EPA should, at a minimum, allow
Wyoming to consider whether this new information would affect its BART
determination before disapproving that determination.
Another commenter suggests that urea prices are relevant to
operating costs for SNCR but are not relevant to SCR. If the State's
urea prices were too low, that would mean the State had underestimated
the cost of SNCR, which is what EPA claims in its proposal. 78 FR
34748. Such an underestimate would have no material impact on the
State's BART determination and thus provides no basis for EPA's
disapproval. Once again, this is a fact that in retrospect supports the
State's BART decision, rather than demonstrating it to be arbitrary. If
Wyoming's estimate of the cost of SNCR should have been higher, as EPA
maintains, the higher cost would tend to add further support for
rejecting SNCR--the more expensive a control technology, the stronger
the reason to reject it as BART. So if EPA is correct in claiming the
State's assumed urea price was too low, it is incorrect in claiming
this made a difference in the State's BART determination. A mistake in
a cost assumption, if there was a mistake, is not a per se reason to
reject a BART determination. Such a mistake would help support
disapproval of a cost analysis and resulting BART determination only if
it overstated costs in a material way and thus tended to make a
technology appear significantly more costly than it actually would be.
Response: We disagree with portions of these comments. As we
explained in responses to similar comments below in the section on
Overarching Comments on BART, we agree that a change in the market
price of urea, in and of itself, may have not provided EPA sufficient
grounds for rejecting the State's SNCR analysis. However, we identified
a number of deficiencies in our proposed rule, that when taken
collectively, led EPA to conclude that Wyoming's consideration of the
costs of compliance and visibility improvement for the EGUs was
inadequate and did not properly follow the requirements in the BART
Guidelines and statutory requirements. 78 FR 34748. Therefore,
regardless of the market price of urea, EPA would have reached the same
conclusion.
Additionally, EPA is required to take into account the urea price
information and we have taken that technical information into account
as detailed elsewhere in this final notice and the
[[Page 5078]]
docket. As explained in detail above, while this information was not
available to the State, EPA nonetheless had a duty to consider any new
information submitted during public comment when reviewing the states'
SIPs. See Sierra Club v. EPA, 671 F.3d 955, 967 (9th Cir. 2012).
Therefore, while the new urea cost information was not available to
the State, EPA was nonetheless obligated to consider any new
information submitted during public comment when reviewing the states'
SIPs. Thus, EPA is required, at a minimum, to take new information into
account during the SIP approval process and, if necessary, alter its
final decision accordingly. Regarding the comment that Wyoming should
get an opportunity to consider this information before EPA takes final
action, see responses to similar comments above.
Comment: EPA relies on its consultant's report as a basis for
rejecting Wyoming's cost analysis for SNCR and proposing to disapprove
the State's NOX BART for Laramie River Station. 78 FR 34748.
EPA may not reject the State's estimate of the NOX reduction
achievable with SNCR just because EPA's consultant disagrees with the
State. Under the appropriate legal standard, EPA must defer to the
State's technical assessment absent demonstration it is arbitrary and
capricious--which EPA has not attempted to prove. Nor can EPA mount a
credible argument that its consultant's report is superior to the
State's. The report does not comply with EPA's own Guidelines, as
interpreted by EPA, and ignores site-specific conditions that have a
huge impact on the cost of NOX emission controls. Given the
flaws in the report, EPA's reliance on it is not only arbitrary and
capricious, but downright astonishing.
Response: We disagree with the commenter's assertion that we have
rejected the State's estimate of cost analysis for SNCR and the
NOX reduction achievable with SNCR just because we disagree
with the State. During the public comment period on our proposed
rulemaking, Basin Electric, as well as other parties, submitted
information concerning cost estimates. We have placed this information
to the docket and as explained elsewhere in this document, taken it
into account as part of this final rulemaking. This final action
clearly explains the basis for our disapproval of State's
NOX BART for Laramie River Station, based on comments
received and our cost and visibility analysis, we are disapproving
others. We also disagree that we are required to defer to the State's
technical judgments and to apply an arbitrary and capricious standard
in reviewing the State's SIP submittal. We respond in detail to those
arguments elsewhere.
Comment: This commenter stated that even if the Wyoming's cost
analyses were revised to reflect the EPA's high urea prices, the
average cost effectiveness of SNCR would still be consistent with the
State's original analyses. The commenter noted that the EPA's average
and incremental cost effectiveness numbers for SNCR fall well below the
values considered by the State to be cost effective and therefore are
consistent with the State's original conclusion that the costs of
compliance from the application of SNCR to the EGUs were reasonable.
The commenter added that even if the State-analyzed urea costs are
adjusted to reflect EPA's urea costs, the average cost effectiveness
values remain below $2,600 dollars per ton of NOX reduced
and with incremental cost effectiveness values below $5,000 dollars per
ton of NOX reduced (citing commenter's Exhibit 10), and
those values are consistent with the State's original conclusion. The
commenter believes that it is clear that the EPA does not take issue
with Wyoming's cost analyses, but rather Wyoming's BART conclusions.
The commenter contended that the EPA's allegation that Wyoming
incorrectly analyzed costs is simply an excuse for EPA to override
Wyoming's BART determinations because EPA does not like the result. The
commenter asserted that the EPA must explain why Wyoming's ultimate
BART determinations run afoul of the law, rather than hold up
allegations of technical deficiencies as window dressing for EPA to
take over the role Congress gave to states to make BART determinations.
Response: We disagree with this comment. As we explained earlier in
this final notice, Congress crafted the CAA to provide for states to
take the lead in developing implementation plans, but balanced that
decision by requiring EPA to review the plans to determine whether a
SIP meets the requirements of the CAA. EPA's review of SIPs is not
limited to a ministerial type of automatic approval of a state's
decisions. EPA must consider not only whether the State considered the
appropriate factors but acted reasonably in doing so. EPA has the
authority to issue a FIP either when EPA has made a finding that the
State has failed to timely submit a SIP or where EPA has found a SIP
deficient. Here, EPA has authority on both grounds, and we have chosen
to approve as much of the Wyoming SIP as possible and to adopt a FIP
only to fill the remaining gap. Our action today is consistent with the
statute. We disagree that technical deficiencies are mere ``window
dressing''; instead, appropriate technical analyses are fundamental to
a reasoned BART determination. Finally, details of technical issues
regarding urea costs are addressed elsewhere in this rule.
Comment: No single factor justifies disapproval of the State's
BART. The authority to determine BART belongs to states, and BART
determinations must be based on all five BART factors weighted
together. States are responsible for balancing those factors and
deciding how much weight to give to each factor. 70 FR 39123, 39130,
39170. To show that Wyoming had been arbitrary and capricious in making
a BART determination, EPA would bear a heavy burden--a burden that it
does not even begin to meet based on a disagreement that the State's
cost analysis for SCR was in error. EPA's own incremental cost
effectiveness for SCR is more than $5000/ton, which is a high cost even
if lower than the State's. EPA makes no attempt to argue that the
difference between its incremental cost effectiveness and the State's
would have changed the State's selection of BART or rendered the
State's BART arbitrary or illegal.
Response: We responded to similar comments elsewhere. First, as we
explain in detail elsewhere, we disagree that EPA's review of a state's
SIP submittal is limited to an arbitrary and capricious standard.
Second, as we explain in detail elsewhere, we disagree that states have
the sole authority to determine BART. Third, as we explain in detail
elsewhere, we disagree that a ``harmless error'' standard should be
applied.
Comment: In June of 2012, EPA issued a proposal that analyzed the
cost effectiveness of various NOX control technologies at
Laramie River Station. 77 FR 33051. Although EPA disagreed with the
State's NOX BART determination for Laramie River Station,
EPA accepted and relied on the State's cost analysis for NOX
controls, which concluded that SCR would cost $3305 per ton of
NOX removed, while SNCR would cost $2036 per ton of
NOX removed. 77 FR 33051, Table 30 (These values are for
Unit 3. The State's conclusions for Units 1 and 2 were similar.) In
light of these estimates, EPA eliminated SCR from consideration at
Laramie River Station ``because the cost effectiveness value is
significantly higher than LNBs with OFA and there is a comparatively
small incremental visibility improvement over LNBs with
[[Page 5079]]
OFA.'' Id. EPA now expressly disavows its earlier finding, apparently
as a result of comments that raised questions with the State's analysis
and a cost analysis prepared by Andover. 78 FR 34740, 34748. Yet EPA's
own cost analysis--based entirely on the findings of a technically
infirm and legally indefensible contractor analysis of the costs of
SNCR and SCR at Laramie River Station--concludes that the cost
effectiveness of SCR at Laramie River Station ranges from $3,589 to
$3,903, which exceed Wyoming's cost effectiveness demonstrations. Id.
at 34774-34775. For EPA to take the position SCR is now cost effective,
based on a higher estimate of tons NOX removed that is
inconsistent with its earlier position and without any further
explanation, is arbitrary and capricious. Cf. W. States Petroleum,
87F.3d at 284 (EPA ``may not depart, sub silentio, from its usual rules
of decision to reach a different, unexplained result in a single
case'').
Response: We disagree with this comment. EPA's June 2012 Federal
Register notice was a ``proposal,'' not a final agency action. Based on
additional information and analyses, on June 10, 2013 we reproposed to
partially approve and partially disapprove the Wyoming SIP. Therefore,
contrary to commenter's assertions, we had not taken a final agency
action in June 2012 and the Western States Petroleum case in not
applicable here. In addition, we fully explained the reasons for the
changes in our proposed action. We note that adjustments in cost-
effectiveness of SCR were not the only factor in our proposed changes.
We also revised modeling of visibility benefits of SNCR and SCR and
cost-effectiveness of SNCR, which played a role in our reproposed BART
determination.
2. Compliance With Section 307(d)
Comment: EPA cannot adopt a FIP using a procedure that
simultaneously proposes both disapproval of a SIP BART determination
and a different BART determination as a FIP. Doing so results in a
violation of Section 307(d), which requires EPA to first announce the
``statement of basis and purpose'' that accompanies the FIP, including
a summary of ``the factual data on which the . . . rule is based'' and
``the major legal interpretations and policy considerations underlying
the . . . rule.'' 42 U.S.C. 7607(d)(1)(B), (d)(3)(A) & (C), (d)(6)(A).
The reason is simple. BART determinations are inherently technical
evaluations that consider costs, feasibility, potential plant shut-
downs, etc. The same requirement would apply to any BART determination
undertaken by EPA as part of a FIP. Thus, any response by EPA to
comments that Basin Electric and others submit in support of Wyoming's
BART determination will necessarily have to deal with new detailed
technical information and data, particularly when, as here, EPA has
initially proposed to reject a BART determination as inadequately
supported and thus has invited extensive comments. EPA's responses to
comments will then necessarily become part of the grounds supporting
any new BART determination in a FIP, but will not have been publicly
disclosed until EPA's response to comments on the SIP. Thus, EPA will
be unable to provide a substantive statement of basis and purpose for
the FIP in the same proposal to disapprove the SIP unless it intends to
ignore comments. Yet this violates EPA's statutory obligation to
announce all the facts and grounds supporting a FIP before adoption. It
also wholly undermines the underlying purposes of the APA's notice and
comment obligations. See, e.g., United States v. Cain, 583 F.3d 408,
420 (6th Cir. 2009) (these obligations are intended to ``ensure fair
treatment for persons to be affected by regulation'' and to ``ensure
that affected parties may participate in decision making at an early
stage''') (citations omitted); NRDC v. Thomas, 805 F.2d 410, 437 (D.C.
Cir. 1986) (the purposes of these obligations include that ``notice
improves the quality of agency rulemaking by ensuring that agency
regulations will be tested by exposure to diverse public comment,''
that ``notice and the opportunity to be heard are an essential
component of fairness to affected parties,'' and that ``by giving
affected parties an opportunity to develop evidence in the record to
support their objections to a rule, notice enhances the quality of
judicial review'') (quoting Small Refiner Lead Phase-Down Task Force v.
EPA, 705 F.2d 506, 547 (D.C. Cir. 1983).
This must be true, unless EPA's proposed course of action has
already been determined, meaning that EPA has already decided to reject
the SIP BART determinations and replace them with its own regardless of
the comments submitted. Such prejudgment would be contrary to law. See,
e.g., Davis v. Mineta, 302 F.3d 1104, 1112 (10th Cir. 2002) (plaintiffs
were likely to prevail in showing agency acted arbitrarily and
capriciously, in part because the agency ``prejudged the NEPA
issues''); Metcalf v. Daley, 214 F.3d 1135, 1146 (9th Cir. 2000)
(agencies' environmental assessment prepared under NEPA was
``demonstrably suspect'' and ``fatally defective'' because the agencies
``were predisposed'' to a particular finding; agencies must conduct
``an objective evaluation free of the previous taint''). Yet that is
plainly what EPA is suggesting by its effort to simultaneously
disapprove one BART determination while proposing another. Either EPA
must ignore the comments so as not to establish new grounds for the
FIP, or it must reject the comments on substantive grounds that become
justification for the FIP but have never been publicly disclosed.
Either way, its action violates APA standards.
This is a consequence of the procedural posture into which EPA has
put itself by taking no action on the SIP until the end of the Sections
110(c) FIP clock. To follow the requirements of Sections 307(d), EPA
must first propose to disapprove a SIP, take comment, and then make a
decision after full and fair consideration of the comments. If, after
open-minded consideration of the comments, EPA continues to believe the
SIP must be disapproved, then and only then can EPA lawfully propose a
different BART determination in a FIP, articulating for public comment
why the proposed federal BART determination is legal and the State BART
determination is not.
Failure to follow this procedure necessarily results in a violation
of the law, one way or another. Nor does the existence of a Consent
Decree excuse EPA's failure to follow the correct procedure. A court-
fashioned decree may not foreclose the total range of procedural
options available to an agency. See Watt v. Energy Action Educ. Found.,
454 U.S. 151, 168-69 (1981) (refusing to limit the procedural options
within the discretion of an agency); Marina T. Larson, Consent Decrees
and the EPA: Are They Really Enforceable Against the Agency?, 1 Pace
Envt'l L. Rev. 147, 160-63 (1983) (arguing that consent decrees may not
limit agency procedural options). EPA waited until compelled by Court
Order to propose disapproval of the State BART determination, but could
have done so much earlier. In any event, the obligations EPA negotiated
for itself in the Consent Decree cannot be used to deprive Wyoming or
Basin Electric the substantive procedural rights afforded by the CAA.
Response: EPA disagrees with this comment, which fundamentally
misunderstands the nature of notice-and-comment rulemaking. As the
Ninth Circuit stated in another context:
Nothing prohibits the Agency from adding supporting
documentation for a final rule in response to public comments. In
fact, adherence to the [petitioners'] view might
[[Page 5080]]
result in the EPA's never being able to issue a final rule capable
of standing up to review: every time the Agency responded to public
comments, such as those in this rulemaking, it would trigger a new
comment period. Thus, either the comment period would continue in a
never-ending circle, or, if the EPA chose not to respond to the last
set of public comments, any final rule could be struck down for lack
of support in the record.
Rybachek v. U.S. EPA, 904 F.2d 1276, 1286 (9th Cir. 1990).
In the context of the CAA, the specific rulemaking provisions in
section 307(d) are in accord with this. Under section 307(d)(3), the
notice for the proposed rule must be accompanied by a statement of
basis and purpose, including ``a summary of (A) the factual data on
which the proposed rule is based; (B) the methodology used in obtaining
the data and in analyzing the data; and (C) the major legal
interpretations and policy considerations underlying the proposed
rule.'' 42 USC 7607(d)(3) (emphasis added). ``All data, information,
and documents referred to in [section 307(d)(3)] on which the proposed
rule relies shall be included in the docket on the date of publication
of the proposed rule.'' Id. (emphasis added). Then, under section
307(d)(6), the promulgated rule must ``be accompanied by (i) a
statement of basis and purpose like that referred to in [section
307(d)(3)] with respect to a proposed rule.'' 42 USC 7607(d)(6)(A)
(emphasis added). In other words, the statement of basis and purpose
must provide a summary of (among other things) the factual data and
methodologies on which the promulgated rule is based. In addition,
section 307(d)(6) specifically requires a ``response to each of the
significant comments, criticisms, and new data submitted . . . during
the comment period.'' 42 USC 7607(d)(6)(B) (emphasis added). And
finally, ``the promulgated rule may not be based . . . on any
information or data which has not been placed in the docket as of the
date of such promulgation,'' id. 7607(d)(C), which by implication
allows EPA to base the promulgated rule on information and data that is
placed in the docket before the date of promulgation. Thus, section
307(d)(6) specifically contemplates that the Agency can in its
promulgated rule rely on additional information and data that EPA
develops after the proposed rule has been published.
In this instance, our FIP proposal was in accord with the
requirements of section 307(d) of the Act. In particular, before the
proposed rule was published, we included in the docket all the factual
data, such as cost estimates and visibility modeling, on which the
proposed rule was based. The comment identifies no deficiency in this
regard. Instead, according to the comment the supposed deficiency is
the failure to include in the docket for the proposal the data and
information that EPA will develop to respond to comments. But, as
discussed above, this is no deficiency; instead section 307(d)
specifically contemplates that this will happen.
The argument in the comment regarding EPA's alleged prejudgment of
its decision also belies a misunderstanding of notice-and-comment
rulemaking. Under the comment's theory, in order to not have
``prejudged'' the outcome, EPA would have to avoid proposing any
particular outcome in its notice of proposed rulemaking. However, under
section 307(d)(3), ``the notice of proposed rulemaking shall be
published in the Federal Register, as provided under section 553(b) [of
the APA].'' Under section 553(b) of the APA, the ``notice shall
include'' (among other things) ``either the terms or substance of the
proposed rule or a description of the subjects and issues involved.'' 5
USC 553(b)(3) (emphasis added). Thus it is of course explicitly
permitted under the CAA and the APA for a proposal notice to contain
EPA's proposed disapproval of the State's BART determinations and EPA's
proposed FIP BART determinations. This does not indicate prejudgment at
all; indeed in this action EPA is adjusting certain determinations in
response to certain comments, and in fact EPA previously reproposed its
action on Wyoming's SIP based upon new information submitted by the
public (77 FR 3302). The cases cited by the comment regarding
prejudgment concern NEPA analysis and are not on point.
As the commenter noted, regional haze requirements apply both to
our action on Wyoming's SIP submittal and our FIP. EPA disagrees that
the BART determinations in its FIP, which must meet the same regional
haze requirements as the BART determinations in Wyoming's SIP, must be
published in a separate rulemaking procedure. To the extent that a
comment on our proposed disapproval was identified as also relevant to
our proposed FIP, we have responded to it. The commenter was not
deprived of procedural rights merely because the commenter could not
submit information twice in two separate rulemakings. All affected
parties had ample opportunity to submit any pertinent information to
EPA.
Regarding the consent decree, we have elsewhere explained that it
did not limit or modify EPA's substantive discretion. With respect to
the comment's argument that it improperly limited EPA's procedural
discretion, any such limits are found in the statutory deadlines and
mandatory duties in the Act itself. The case cited in the comment, Watt
v. Energy Action Educ. Found., 454 U.S. 151 (1981), did not concern a
consent decree and is not on point. In it, the Supreme Court was
``unable to find anything, either in the legislative history or in the
1978 Amendments [to the Outer Continental Shelf Lands Act] themselves,
that compels the conclusion that the Congress as a whole intended to
limit the Secretary of the Interior's discretion'' with respect to
choice of bidding systems for oil and gas leases. Id. at 168. By
contrast, the CAA sets certain statutory deadlines for EPA's action on
SIP submittals and FIP promulgations and thereby explicitly limits the
Administrator's discretion for final action. We elsewhere respond to
comments that EPA's promulgation of its FIP was outside EPA's authority
under 110(c) of the Act. Finally, the cited law review article, Marina
T. Larson, Consent Decrees and the EPA: Are They Really Enforceable
Against the Agency?, 1 Pace Envt'l L. Rev. 147 (1983), is also not on
point. It discusses a settlement agreement which ``set[ ] forth
specific methods and formalized criteria for the [A]dministrator to use
in assessing the need for regulation. These rules [would] control the
nature of the data collected and its subsequent interpretation, and
[would] have a significant influence on the substantive decisions
reached.'' Id. at 162. No such constraints have been placed on our
methods and use of data in the aforementioned consent decree. We
respond elsewhere to comments about procedural due process rights.
3. Compliance With Section 169A(d)
Comment: One commenter argued that section 169A(d) of the CAA
requires that before holding a hearing on a proposed regional haze
plan, ``the State (or the Administrator, in the case of a [FIP]), shall
consult in person with the appropriate federal land manager (FLM) or
managers and shall include a summary of the conclusions and
recommendations of the FLMs in the notice to the public.'' 42 U.S.C.
7491(d). In its proposed action, EPA recites this land manager
consultation requirement as it applies to SIPs, 78 FR 34744, but, EPA
notably ignores that this requirement applies equally to FIPs.
[[Page 5081]]
The commenter asserted that not once in any of EPA's public notices
of the hearings EPA held on its proposed FIP did EPA include a summary
of the conclusions and recommendations of the FLMs in the notice to the
public. See 78 FR 34738 (June 10, 2013); 78 FR 40654 (July 8, 2013).
Consequently, the commenter argued that EPA cannot rely on the State's
public notices because the State held its public hearings years before
EPA proposed its FIP and because the SIP differs substantially from the
FIP.
The commenter argued that EPA's failure to comply with Section
169A(d) can be understood only as arbitrary and capricious. The CAA has
required consultation with FLMs, which oversee the Class I areas the
regional haze program aims to protect, from the very beginning of the
regional haze program, see 42 U.S.C. 749l(a)(2), and continuously
through the development of each implementation plan, id. Sections
749l(d). Congress therefore understood the importance of working
closely with FLMs in regional haze planning.
In 1999, EPA plainly understood the significance of consulting the
FLMs when it promulgated the RHR. See 64 FR 35714, 35747 (July 1, 1999)
(describing land manager consultation as ``important and necessary'').
Both times EPA proposed action on Wyoming's SIP--in 2012 and again in
2013--EPA reiterated the need to consult with FLMs when developing a
regional haze implementation plan. 77 FR 33022, 33028 (June 4, 2012);
78 FR 34738, 34744-45 (June 10, 2013).
Against this backdrop, the commenter explained, EPA's failure to
explain why EPA believed it did not have to consult with the FLMs when
promulgating its FIP for Wyoming, let alone comply with the simple
consultation process set forth in Section 169A(d), is plainly arbitrary
and capricious. Because FLMs play a critical statutory role in the
regional haze program, there is a substantial likelihood that EPA's
proposed FIP would be significantly different if EPA had complied with
Section 169A(d).
Response: EPA agrees that consultation with the FLMs is an
important aspect of the regional haze program. EPA has engaged with the
appropriate FLMs on all of its regional haze actions, including its
proposed actions on the Wyoming regional haze SIP. While EPA did not
include a summary of the FLMs' conclusions and recommendations on the
proposed FIP in the public hearing notices, those conclusions and
recommendations are readily available to the public in the online
docket for this rulemaking.\54\
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\54\ EPA-R08-OAR-2012-0026-0134, and EPA-R08-OAR-2012-0026-0068.
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EPA also disagrees with the commenter that the consultation
materials contained in the State's public notices are irrelevant just
because the State conducted its public hearings many years ago. The
FLMs concluded at that time that the Wyoming regional haze SIP did not
adequately protect the State's Class I areas, and these conclusions and
recommendations informed EPA when we proposed to disapprove portions of
the Wyoming regional haze SIP and issue a FIP.
Finally, there is no basis to the commenter's claim that EPA's
proposed FIP would be significantly different if we had included the
FLMs' conclusions and recommendations in the public hearing notices. We
carefully considered the comments of the FLMs and have responded to
them elsewhere throughout this document. As those responses explain in
more detail, we have chosen not to change our proposed NOX
BART determinations in all of the ways in which the FLMs requested. We
point out, however, that had EPA adopted the FLMs' recommendations, we
would be requiring SCR on all of the BART-eligible EGUs in Wyoming, a
result that this particular commenter has vigorously opposed.
Comment: The processes Congress required EPA to follow under the
regional haze program were circumvented. For example, the CAA requires
both states and EPA to consult with FLMs on regional haze
implementation plans. Public notice of the FLMs' conclusions and
recommendations is to occur before holding a hearing on the plan. While
EPA recites this requirement in its proposed action, it utterly failed
to include any FLM consultation on behalf of its agency. EPA held three
hearings and not once in any hearing did the EPA indicate it had
consulted the FLMs in Wyoming and no conclusions or recommendations of
any consultations were provided.
Response: See above response.
4. Public Hearings
Comment: EPA's regional haze plan promulgation regulations require
EPA to provide public notice at least thirty days in advance of a
hearing on a proposed implementation plan. 40 CFR 51.102(d) (a plan
hearing ``will be held only after reasonable notice, which will be
considered to include, at least 30 days prior to the hearing(s)''); see
also 40 CFR 51.100(i). Although EPA held three public hearings on its
proposed FIP for Wyoming, not once did EPA provide the public at least
thirty days advance notice of the hearing. EPA proposed its FIP on June
10, 2013 and provided only fourteen days notice of its hearing on the
proposal. 78 FR 34738, 34738. After Governor Mead, Wyoming's
Congressional Delegation, and the Wyoming Department of Environmental
Quality (DEQ) pointed out to EPA that fourteen days provided far too
inadequate notice for the public to understand the proposed FIP and
therefore meaningfully participate in the public hearing, EPA agreed to
hold two additional hearings. On July 8, 2013, EPA publicly noticed its
plans to hold the additional hearings on July 17, 2013 and July 26,
2013. 78 FR 40654, 40654. Thus, although EPA had the opportunity to
correct its errors, it failed to do so by again providing less than
thirty days notice of its hearings.
Here again, EPA's noncompliance with its own regulatory processes
is arbitrary and capricious. EPA cannot ignore the law for its own
benefit without at least providing a reasoned justification for doing
so. In this case EPA has provided no such explanation, thereby
rendering its failure an arbitrary abuse of power. And by shortcutting
public participation, EPA undermined the central democratic purposes of
notice-and-comment rule-making. Had EPA honored the law and held itself
to the same standards it holds states, the public could have more
meaningfully commented on EPA's proposal. As a result of that public
input, EPA's proposed FIP might be considerably different, assuming, as
we must, that EPA would have considered those comments with an open
mind.
DEQ understands that EPA rushed its FIP promulgation process in
order to meet the deadlines it consensually established with a third
party in litigation to which Wyoming was not a party. But, EPA's
outside arrangements do not excuse it from complying with the law, or
allow it to shortcut public participation in the promulgation of a
rule, especially one that will harm Wyoming. DEQ discourages EPA from
imposing its illegally promulgated FIP on Wyoming. But, in the event
EPA decides nevertheless to do so, DEQ encourages EPA to re-propose its
FIP in a manner that complies with the statutory and regulatory plan
development processes. To do otherwise is to arbitrarily hold states to
a different plan promulgation standard than EPA itself adheres to, even
though the CAA makes no such distinction. Such irrationally unequal
treatment is the essence of arbitrary regulation.
[[Page 5082]]
Response: EPA disagrees with this comment. First, 40 CFR 51.102(d)
implements the requirement in section 110(a)(2) that state plans ``be
adopted by the State after reasonable notice and hearing.'' See 72 FR
38787 (July 16, 2007). When EPA--which is not a state--promulgates a
FIP, EPA instead is bound by the requirements in section 307(d) of the
Act. EPA has not promulgated specific regulations governing EPA's
processes under section 307(d); however, EPA complied with the public
hearing requirements in 307(d) as explained below. The definition of
``State agency'' in 51.100(i) does not contradict this; indeed the
commenter elsewhere protests vigorously elsewhere that states, not EPA,
are ``primarily responsible for development and implementation of a
plan under the Act.'' 40 CFR 51.100(i). Thus, EPA does not fall under
the definition of ``State agency.'' We also note that EPA initially
provided a 60-day comment period for this action and then extended it
15 more days; under 40 CFR 51.102. States need only provide a 30-day
period for written comments. See 72 FR at 38788 (``Whether or not a
public hearing is held, the State is required to provide a 30-day
period for the written submission of comments from the public.'').
In promulgating a FIP under CAA section 110(c), EPA is required to:
``give interested persons an opportunity for the oral presentation of
data, views, or arguments, in addition to an opportunity to make
written submissions; keep a transcript of any oral presentation; and
keep the record of such proceeding open for thirty days after
completion of the proceeding to provide an opportunity for submission
of rebuttal and supplementary information.'' \55\ In this rulemaking,
EPA held three public hearings on its proposed FIP. In addition to the
public hearing initially scheduled on June 24, 2013 in Cheyenne,
Wyoming, additional public hearings were held on July 17, 2013 in
Cheyenne, Wyoming and on July 26, 2013 in Casper, Wyoming. The
transcripts for those hearings consisted of 321 pages. These hearings
were announced in the Federal Register on June 10, 2013 and July 8,
2013,\56\ and a pre-publication version of the proposal was posted on
EPA's Web site prior to publication in the Federal Register. The
proposal was published in the Federal Register on June 10, 2013 and was
initially scheduled to close on August 9, 2013. The public comment
period was extended in response to letters received from the Governor
and Congressional delegation, which are in the docket for this action,
and public comments were accepted through August 26, 2013, 30 days
after the last hearing, as required. EPA received over 1900 comments on
the reproposal, including over 130 unique comments submitted from
organizations, companies, and individuals. The major comments consisted
of over 1130 pages, including attachments. The commenters have not
explained how their ability to comment was impaired in any way by the
opportunities for public comment that EPA provided, including three
public hearings and the 75-day comment period.
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\55\ See CAA section 307(d).
\56\ 78 FR 34738, and 78 FR 40654.
---------------------------------------------------------------------------
Comment: EPA failed to follow its own rules for providing public
notice of hearings on regional haze implementation plans. Those rules
require a minimum of 30 days advance public notice of hearings on
implementation plans. The first notice in the Federal Register of a
public hearing was issued on June 10, 2013, for a public hearing to be
held on June 24, 2013. EPA issued a second notice for additional public
hearings on July 8, 2013 in the Federal Register. The notice identified
July 17, 2013 and July 26, 2013 as dates set. This provided the public
nine and eighteen days notice of the respective hearings.
Response: We disagree with this comment, see above response.
5. RHR and BART Guidelines
Comment: Regardless of the effect of AFUDC on cost effectiveness as
demonstrated by the Sargent & Lundy sensitivity analyses, EPA has no
authority, as part of its interpretation of a non-binding guidance
document, to impose restrictions on the categories of costs that states
can include when assessing the ``costs of compliance'' in a BART
determination. EPA has failed to make a showing that Wyoming's
compliance with Sections 169A(g)(2) or otherwise violates governing
law. Including AFUDC is not a lawful ground for disapproving Laramie
River Station BART, and it is improper to exclude AFUDC in EPA's FIP
analysis for Laramie River.
Response: EPA disagrees with this comment. EPA's revised cost-
effectiveness values are consistent with EPA's regulations and the
parameters set forth in the Control Cost Manual. EPA explained in
promulgating the BART Guidelines that ``[s]tates have flexibility in
how they calculate costs. ``See 70 FR at 39127 (July 6, 2005). A state
may deviate from the Control Cost Manual provided its analysis is
reasonable. EPA independently evaluated Sargent & Lundy cost-
effectiveness calculation, explaining elsewhere in this document that
the CCM explicitly excludes AFUDC from control costs, and EPA's
estimates were correct in excluding AFUDC. See Oklahoma v. U.S. EPA,
723 F.3d 1201, 1212 (10th Cir. 2013) (``The EPA therefore had a
reasonable basis for rejecting the 2008 Cost Estimates [that were based
on the overnight costing method] as not complying with the
guidelines.'')
Furthermore, as Region 9 explained in responding to similar
comments: \57\
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\57\ 77 FR 72512, 72531 (Dec. 5, 2012)(BART for Apache, Cholla
and Coronado).
EPA disagrees ``with commenters' assertions that AFUDC is a cost
that should be incorporated into our cost analysis, as it is
inconsistent with CCM methodology. The utility industry uses a
method known as ``levelized costing'' to conduct its internal
comparisons, which is different from the methods specified by the
CCM. Utilities use ``levelized costing'' to allow them to recover
project costs over a period of several years and, as a result,
realize a reasonable return on their investment. The CCM uses an
approach sometimes referred to as overnight costing, which treats
the costs of a project as if the project were completed
``overnight'', with no construction period and no interest accrual.
Since assets under construction do not provide service to current
customers, utilities cannot charge the interest and allowed return
on equity associated with these assets to customers while under
construction. Under the ``levelized costing'' methodology, AFUDC
capitalizes the interest and return on equity that would accrue over
the construction period and adds them to the rate base when
construction is completed and the assets are used. Although it is
included in capital costs, AFUDC primarily represents a tool for
utilities to capture their cost of borrowing and return on equity
during construction periods. AFUDC is not allowed as a capitalized
cost associated with a pollution control device under CCM's
overnight costing methodology, and is specifically disallowed for
SCRs (i.e., set to zero) in the CCM.\58\ Therefore, in reviewing
other BART determinations, EPA has consistently excluded AFUDC.\59\
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\58\ CCM (Tables 1.4 and 2.5 show AFUDC value as zero).
\59\ See, e.g., 77 FR 20894, 20916-17 (Apr. 6, 2012) (explaining
in support of the North Dakota Regional Haze FIP, ``we maintain that
following the overnight method ensures equitable BART determinations
. . .''); 76 FR 52388, 52399-400 (August 22, 2011) (explaining in
the New Mexico Regional Haze FIP that the Manual does not allow
AFUDC).
Comment: EPA claims that Wyoming should have used actual emissions
during the baseline period instead of calculating baseline emissions
from the actual average heat input and actual average emission rate.
EPA apparently claims that this deviated from the BART Guidelines. 78
FR 34773-34774.
[[Page 5083]]
However, the Guidelines do not mandate EPA's approach. They say,
rather, that the baseline emissions rate ``should represent a realistic
depiction of anticipated annual emissions for the source'' and ``in
general'' states should estimate anticipated emissions based on actual
baseline emissions. 70 FR 39167. Nothing in the text of the Guidelines
requires states to use any particular approach to estimate future
emissions. The Guidelines were constructed to assist the states in
making cost assessments, not to mandate the same assessment and the
same results in every case by use of mandatory checklists. The word
``should'' in the Guidelines makes clear there is no mandatory action
required. See Aragon v. United States, 146 F.3d 819, 826 (10th Cir.
1998) (describing Air Force Manual 85-14's use of the word ``should''
as ``suggestive, rather than mandatory language'' in a Federal Tort
Claims Act case); In re Glacier Bay, 71 F.3d 1447, 1452-53 (9th Cir.
1995) (interpreting the National Oceanic and Atmospheric
Administration's use of the word ``should'' in manuals and instructions
as ``suggestive'' language conferring hydrographers with discretion);
Culbert v. Young, 834 F.2d 624, 628 (7th Cir. 1987) (holding that use
of the word ``should'' in a Wisconsin Administrative Code provision
governing inmate discipline ``only advises the security director on
what criteria to consider but does not require him to consider them,''
and explaining that ``[t]he word `should,' unlike the words `shall,'
`will,' or `must,' is permissive rather than mandatory''). See also
Dickson v. Sec'y of Defense, 68 F.3d 1396, 1401 (D.C. Cir. 1995)
(``When a statute uses a permissive term such as `may' rather than a
mandatory term such as `shall,' this choice of language suggests that
Congress intends to confer some discretion on the agency, and that
courts should accordingly show deference to the agency's
determination.'') (emphasis omitted).
EPA is therefore merely disagreeing with a judgment call made by
the State, not pointing to violation of a mandatory methodology. And,
even though not required to do so, Wyoming did follow the
recommendation in the Guidelines. Although EPA contends that the State
used a baseline based on annual average heat input for 2001-2003 and an
emission rate of 0.27 rather than the ``actual annual average''
emissions, 78 FR 34773-34774, the State's May 28, 2009 BART Analysis
actually says ``[b]aseline emissions [are] based on continuous
emissions monitoring (CEM) annual averages for 2001-2003.''
But even if EPA were correct, EPA would still be wrong in asserting
that the State failed to follow the BART Guidelines. The approach that
EPA objects to would be an appropriate method to realistically depict
anticipated annual emissions. Certainly it would be reasonable to
multiply the actual annual amount of heat in Laramie River coal during
the baseline period by the same baseline emission rate of 0.27 lb/MMBtu
that was used by EPA's own consultant. 78 FR at 34773; Review of
Estimated Compliance Costs for Wyoming Electric Generating (EGUs)--
Revision of Previous Memo, memo from Jim Staudt, Andover Technology
Partners, to Doug Grano, EC/R, Inc., Feb. 7, 2013 (``Andover Report'')
at 15 Table 4, EPA docket cite EPA-R08-OAR-2012-0026-0086. Any estimate
of anticipated emissions is necessarily a projection, and by definition
cannot require exclusive reliance on past actual emissions.
That the State's approach to baseline emissions was a realistic
projection is borne out by the fact that the annual baseline emissions
the State used to calculate cost effectiveness for Laramie River
differs from EPA's baseline by only the following de minimis amounts:
269 tons higher than EPA's 6051 tons for Unit 1, a difference of only
4%; 8 tons lower than EPA's 6285 tons for Unit 2, a difference of only
0.1%; and 73 tons higher than EPA's 6375 tons for Unit 3, a difference
of only 1%. No fair assessment could conclude that such de minimis
differences violate the Guidelines or yield an ``implausible'' result
so extreme as to be arbitrary and capricious. 78 FR 34773-34776.
If EPA's values are realistic, the State's values are realistic.
There is no material difference between them. The objective of a BART
determination is to arrive at a technology selection that weighs and
takes into account the five BART factors. The negligible difference
between EPA's baseline emissions and the State's is not material and
therefore is not a valid ground for disapproving the State's
NOX BART for Laramie River, and EPA has made no effort to
show otherwise. EPA's role is not to fly speck each and every aspect of
the BART process in a search for reasons to disapprove the State's
determination.
In fact, EPA proposes to approve other BART determinations made by
Wyoming despite the same alleged ``errors,'' unequivocally
demonstrating that its disagreement with Wyoming's approach to baseline
calculations does not amount to proof of a legal violation by the
State. EPA claims that for several Wyoming sources subject to BART,
Wyoming committed the same ``cost and visibility errors'' that EPA
claims for Laramie River, but proposes nonetheless to approve the BART
determinations for these sources ``because we have determined that the
State's conclusions were reasonable despite the cost and visibility
errors.'' 78 FR 34750. EPA contradicts itself when it overlooks errors
for other sources and yet claims those same ``errors'' as per se
reasons to disapprove BART for Laramie River Station. Such inconsistent
treatment is erroneous. See W. States Petroleum v. EPA, 87 F.3d 280,
282 (9th Cir. 1996). EPA's own behavior therefore demonstrates that the
baseline used for Laramie River is not a material departure from any
requirement and is not a basis for disapproval of the State's BART
determination. EPA is stretching to find any excuse to impose its own
technology preferences, contrary to law.
Wyoming's choice of baseline emissions is neither inconsistent with
the BART Guidelines nor materially different from EPA's allegedly
correct baseline emissions, and therefore is not a valid ground for
disapproving Wyoming's NOX BART for Laramie River.
Response: We disagree with some aspects of this comment, but agree
with others. First, we disagree with the commenter's characterization
of the BART Guidelines as other than mandatory in the case of Laramie
River Station, including in regard to how baseline emissions are
calculated. The generating capacity of Laramie River Station of 1,705
MW surpasses the threshold of 750 MW used to determine whether the BART
Guidelines must be applied. As stated in the RHR: ``The determination
of BART for fossil-fuel fired power plants having a total generating
capacity greater than 750 megawatts must be made pursuant to the
guidelines in appendix Y of this part (Guidelines for BART
Determinations Under the Regional Haze Rule).'' \60\ Moreover, the
commenter's attempts to turn ``should'' into ``may'' are of no avail.
Because the BART Guidelines are mandatory for EGUs larger than 750 MW,
EPA's use of the word ``should'' indicates a mandate, not a suggestion.
Elsewhere in the Guidelines, EPA uses ``may'' when EPA means ``may.''
See, e.g. 40 CFR Part 51, App'x Y, II.A.4 (``In order to simplify BART
determinations, States may choose to identify de minimis levels of
pollutants at BART-eligible sources (but are not required to do so).'')
(emphasis added). Furthermore, the Tenth Circuit Court of Appeals has
interpreted ``should'' in the Guidelines to mean ``required.'' See
[[Page 5084]]
Oklahoma v. U.S. EPA, 723 F.3d 1201, 1213 (10th Cir. 2013) (``The
guidelines require that states provide support for any site-specific
costs that depart from the generic numbers in the Control Cost Manual.
See 40 CFR part 51 app. Y(IV)(D)(4)(a) n.15 (``You should include
documentation for any additional information you used for the cost
calculations, including any information supplied by vendors that
affects your assumptions regarding purchased equipment costs, equipment
life, replacement of major components, and any other element of the
calculation that differs from the Control Cost Manual.'')'') (emphasis
added).
---------------------------------------------------------------------------
\60\ 40 CFR 51.302(e)(1)(ii)(B) (emphasis added).
---------------------------------------------------------------------------
Notwithstanding that the BART Guidelines are mandatory for Laramie
River Station, we agree that Wyoming's approach, having used both the
actual NOX emission rate and the actual heat input from the
baseline period, resulted in a realistic depiction of anticipated
annual emissions consistent with the BART Guidelines, that these
emissions differed only slightly from baseline emissions estimated by
EPA and that, therefore, Wyoming's treatment of baseline emissions by
itself was not a basis for EPA to disapprove NOX BART for
Laramie River Station. Nonetheless, as discussed in response to other
comments, we maintain that there were other deficiencies in Wyoming's
BART analysis for Laramie River Station that remain a valid basis for
our disapproval. Most notably, Wyoming did not consider the visibility
impacts of SNCR as required by the CAA and BART Guidelines.
Comment: Against its longstanding 30-year history of interpreting
and applying the RHR and Guidelines, EPA has now embarked on a spate of
BART disapprovals demonstrating that the agency is now interpreting and
applying the Guidelines and CCM very differently than it did in the
past, and signaling that EPA has actually decided to reinterpret the
statute and Guidelines without notice and comment to the states.
EPA is manufacturing requirements in the Guidelines that do not
exist, for the purpose of abandoning the administrative structure
conferring state primacy that Congress created with both the CAA
generally and the Regional Haze Statute in particular. EPA is doing so
by interpreting the BART Guidelines and CCM as setting forth detailed,
mandatory regulatory requirements that are not actually in the text,
and by seeking to make any deviation from the recommendations in the
Guidelines or CCM grounds for voiding states' BART choices.
EPA is attempting to convert recommendations into mandates. This
new interpretation of the Guidelines and Cost Manual is erroneous,
contrary to their statutory role, unannounced, and calculated to
federalize BART decisions by making them all follow identical paths
whether or not local considerations and costs warrant separate
treatment in control decisions.
Response: Our proposal clearly laid out the bases for our proposed
approval and disapproval of the State's BART and reasonable progress
determinations, as well as other SIP elements. We have relied on the
standards contained in our regional haze regulations and the authority
that Congress granted us to review and determine whether SIPs comply
with the minimum statutory and regulatory requirements.\61\ To the
extent we have found that the State's cost analysis relies on values
that do not conform to applicable requirements of the Act and
regulations, we have disapproved those elements of the analysis. To the
extent the state has considered visibility improvement from potential
emissions controls in a way that is inconsistent with the CAA and
regulations, we have disapproved those elements of the analysis.
---------------------------------------------------------------------------
\61\ EPA is responsible for reviewing State-submitted SIPs and
SIP revisions to ensure that they ``meet[ ] all of the applicable
requirements of [the Act].'' CAA Section 110(k)(3); see also CAA
Section 110(l) (EPA shall not approve SIP revision if it would
interfere with ``any . . . applicable requirement of this
chapter''); Oklahoma, 723 F.3d at 1204 (EPA reviews all SIPs to
ensure plans comply with the Act). There is nothing unusual about
regional haze SIPs in this regard--they, like any other SIPs, must
be reviewed by EPA, and may be approved only if they meet all
applicable requirements of the Act, including provisions related to
visibility. See Oklahoma, 723 F.3d at 1207; North Dakota, 730 F.3d
at 756-57.
---------------------------------------------------------------------------
Where, as explained in our proposed notice and final notice, a
state determines that a less stringent control technology is the ``best
available,'' as was the case here with regard to NOX
emissions, the state must justify its decision by explaining how the
BART factors led it to choose that level of control over more stringent
options. See 70 FR 39170-71. While a state has significant discretion
regarding how to conduct its BART analysis, EPA must ultimately ensure
that the state has demonstrated it has a reasoned basis, consistent
with the Act's requirements, for determining that a given emissions
control technology is ``the best available'' for each source. See
Oklahoma, 723 F.3d at 1208 (``[W[hile it is undoubtedly true that the
statute gives states discretion in balancing the five BART factors, it
also mandates that the state adhere to certain requirements when
conducting a BART analysis.'').
In determining SIP adequacy, we inevitably exercise our judgment
and expertise regarding technical issues, and it is entirely
appropriate that we do so. Courts have recognized this necessity and
deferred to our exercise of discretion when reviewing SIPs. See, e.g.,
Connecticut Fund for the Env't., Inc. v. EPA, 696 F.2d 169 (2nd Cir.
1982); Michigan Dep't. of Envtl. Quality v. Browner, 230 F.3d 181 (6th
Cir. 2000); Mont. Sulphur & Chem. Co. v. EPA, 666 F.3d 1174, 1190 (9th
Cir. 2012) cert. denied, 133 S. Ct. 409, (2012). Contrary to the
commenter's assertion, we have not abandoned the State's primacy. In
fact, we have approved the vast majority of the State's determinations.
We are only disapproving the State's analyses and decisions that do not
conform to the CAA and regulations. We are authorized to do so.
Comment: As early as 1979, EPA recognized that the regional haze
program is organized around ``goals'' and ``reasonable progress,'' and
not hard objective requirements: Section 169A of the CAA provides for
consideration of the degree or significance of visibility improvement,
costs, energy, and other factors in applying retrofit controls to major
sources and in making ``reasonable'' progress toward the national goal.
These provisions indicate that some flexibility can be allowed in
implementing control programs for remedying existing impairment and
that priorities can be established.
Thus, while the BART analysis may include consideration of factors
similar to those applied in a BACT analysis, BART does not require any
threshold level of control. As EPA acknowledged in its 2004 re-proposal
of the BART Guidelines, ``for the BART analysis, there is no minimum
level of control required.'' 69 FR. 25184, 25219 (May 5, 2004). The
RHR's ``national goal'' is not a mandate but, rather, a foundation for
analytical tools to be used by the states in setting RPGs. The BART
Guidelines were therefore developed to assist states in making their
own BART determinations by providing analytical tools. They were not
designed or intended by Congress to impose inflexible mandates that
become tripwires for EPA to use as a means of federalizing BART
decisions with set criteria. EPA's current effort to convert the
Guidelines into something they were not intended to be is improper and
calculated to shift to EPA authority over BART determinations that
Congress reserved to the states. ``[A]n agency cannot create
regulations which are beyond the scope of its delegated authority.''
Nagahi v. INS, 219 F.3d 1166, 1169 (10th Cir. 2000). Nor can an agency
reinterpret regulations for that purpose.
[[Page 5085]]
Congress authorized EPA to provide guidelines only as to limited
aspects of a state's BART decision-making process, and left the
majority of that process to the states' discretion. Specifically, in
the subsection immediately preceding the reference to the Guidelines,
Congress directed EPA to conduct a study on available methods for
implementing the national goal and provide recommendations to Congress
for (1) ``methods for identifying, characterizing, determining,
quantifying, and measuring visibility impairment in Federal areas'';
(2) ``modeling techniques (or other methods) for determining the extent
to which manmade air pollution may reasonably be anticipated to cause
or contribute to such impairment''; and (3) ``methods for preventing
and remedying such manmade air pollution and resulting visibility
impairment.'' CAA Sections 169A(a)(3)(A)-(C), 42 U.S.C. 7491(a)(3)(A)-
(C).
In the next subsection, Congress directed EPA to promulgate
regulations--but with any regulation of the states' BART determinations
confined to those limited areas on which EPA had been directed to
conduct studies and make a report to Congress. Specifically, CAA
Section 169(b) provides, in pertinent part, that the regulations
``shall--(1) provide guidelines to the States, taking into account the
recommendations under subsection (a)(3) of this section on appropriate
techniques and methods for implementing this section (as provided in
subparagraphs (A) through (C) of such subsection (a)(3)), and (2)
require each applicable implementation plan for a State . . . to
contain such emission limits, schedules of compliance and other
measures as may be necessary to make reasonable progress toward meeting
the national goal.'' Id. Sections 7491(b)(1)-(2).
Accordingly, Congress only authorized EPA to promulgate regulations
or guidelines on the identification and measurement of visibility
impairment, the methods for measuring and predicting future visibility
impairment, the methods for preventing and remedying air pollution and
resulting visibility impairment, and the CAA's general requirement that
states develop SIPs to include the BART and reasonable progress
determinations required by the RHR. Congress did not authorize EPA to
promulgate regulations or guidelines mandating exactly how the states
should conduct their BART analyses, and made clear that the purpose of
the guidelines was to provide ``recommendations'' to the states.
Consistent with the statute and regulations, the BART Guidelines
contemplate a two-step process: (1) the ``Attribution Step,'' which
consists of analyzing which sources are appropriately subject to BART
controls; and (2) the ``Determination Step,'' which consists of
determining, based on the five statutory BART factors, an appropriate
level of control. 70 FR 39108, 39126; see also Utility Air Regulatory
Group, 471 F.3d at 1335-36 (discussing two-step process). The
Guidelines for the Determination Step are designed as a ``step-by-step
guide'' for states to identify the ``best system of continuous
emissions control technology,'' taking into account the five BART
factors. 70 FR 39127. See also id. at 39158 (the Guidelines describe a
``process for making BART determinations''). They are merely ``helpful
guidance'' for sources other than power plants with a capacity greater
than 750 MW. Id. at 39108; Utility Air Regulatory Group, 471 F.3d at
1339. Yet, even for larger power plants, the Guidelines are procedural
in nature, setting forth criteria for evaluating control alternatives,
but not mandating a substantive result. As EPA acknowledges, to mandate
a choice of technology would infringe on ``those areas where the Act
and legislative history indicate that Congress evinced a special
concern with insuring that States would be the decision makers.'' 70 FR
39137. See also id. at 39107 (``The State must determine the
appropriate level of BART control'').
The flexibility afforded by the Guidelines is critical to ensuring
that states maintain primacy in making BART determinations. When EPA
re-proposed the Guidelines in 2004, for example, EPA requested comment
on a sequential process--similar to a BACT analysis--for considering
the five statutory BART factors. 69 FR 25197-25198. In the final rule,
however, EPA concluded that ``States should retain the discretion to
evaluate control options in whatever order they choose, so long as the
State explains its analysis of the CAA factors.'' 70 FR 39130. EPA also
expressed that the Guidelines confer authority on the state to make ``a
BART determination based on the estimates available for each criterion,
and as the CAA does not specify how the state should take these factors
into account, the states are free to determine the weight and
significance to be assigned to each factor.'' Id. at 39123.
EPA further emphasized the flexibility inherent in each step of the
BART determination: ``States have flexibility in how they calculate
costs,'' id. at 39127, and ``have the flexibility to develop their own
methods to evaluate model results,'' id. at 39108. EPA points out that
``States should have flexibility when evaluating the fifth [visibility]
statutory factor.'' Id. at 39129. See also id. (``Because each Class I
area is unique, we believe States should have flexibility to assess
visibility improvements due to BART controls by one or more methods, or
by a combination of methods . . .''). Even the presumptive emission
limits for power plants greater than 750 MW ``are presumptions only; in
making a BART determination, states have the ability to consider the
specific characteristics of the source at issue and to find that the
presumptive limits would not be appropriate for that source.'' Id. at
39134.
Response: EPA agrees that states play an important role in the
regional haze program. However, EPA disagrees that this action
conflicts with the State's statutory role or that this rule is beyond
EPA's authority. First, the regional haze program explains that EPA
``shall . . . require each applicable implementation plan for a State .
. . to contain such emission limits, schedules of compliance, and other
measures as may be necessary to make reasonable progress toward meeting
the national goal.'' 42 U.S.C. 7491(b)(2). The CAA makes clear that EPA
is statutorily obligated to reject a SIP that would ``interfere with
any applicable requirement concerning attainment and reasonable further
progress . . . or any other applicable requirement of this chapter.''
42 U.S.C. 7410(l). Thus the CAA provides EPA with the authority to
review and reject an inadequate regional haze SIP. Oklahoma v. EPA, 723
F.3d 1201, 1207 (10th Cir. 2013); North Dakota v. EPA, 730 F.3d 750
(8th Cir. 2013).
Second, EPA is required to establish guidelines to ensure that
states achieve the visibility goals set forth in the Act. 42 U.S.C.
7491(b)(1). EPA agrees that states have some flexibility in BART
determinations, but that flexibility is limited and states must provide
EPA with reasoned analysis for their SIP decisions. Oklahoma v. EPA,
723 F.3d 1201, 1207 (10th Cir. 2013) (noting that while ``it is
undoubtedly true that the statute gives states discretion in balancing
the five BART factors, it also mandates that the state adhere to
certain requirements when conducting a BART analysis''); North Dakota
v. EPA, 730 F.3d 750 (8th Cir. 2013) (explaining EPA is not required to
``approve a BART determination that is based upon an analysis that is
neither reasoned nor moored to the CAA's provisions''). The regional
haze guidelines provide states
[[Page 5086]]
with methods to determine BART that EPA considers reasonable, although
states may consider methods not provided for in the guidelines in
certain circumstances. For example, in explaining a state's flexibility
to determine costs, the guidelines note that ``if there are elements or
sources that are not addressed by the Control Cost Manual or there are
additional cost methods that could be used, we believe that these could
serve as useful supplemental information.'' 70 FR No. 128 39127. (July
6, 2005). A state, however, must demonstrate that any methods it has
used to determine BART that are not found within the guidelines are
reasonable.
EPA may, and has, approved state BART determinations that do not
rigidly follow the BART guidelines, so long as the state's
determinations are reasonable. Here, however, Wyoming's methods were
inconsistent with the BART guidelines, unreasonable, and inconsistent
with the CAA's statutory and regulatory requirements, as explained
elsewhere in these comments. Nothing in this rule displaces a state's
discretion to balance the five factors, if the state calculates the
factors using reasonable methods that are consistent with the
regulatory and statutory requirements of the CAA.
Comment: EPA is now construing the BART Guidelines to treat
``recommendations'' as ``mandates'' such that states no longer have the
authority to vary from the recommendations, however insignificantly,
without finding EPA disapproving their BART determinations. Such an
interpretation violates both the plain language of the CAA and its
underlying cooperative federalism structure. First, Section
169A(b)(2)(A) provides that BART shall ``be determined by the State.''
42 U.S.C. 7491(b)(2)(A). Section 169A(g)(2) provides that states are to
determine the ``costs of compliance'' and the ``degree of improvement
in visibility.'' Id. Section 7491(g)(2). Any interpretation and
application of the BART Guidelines and CCM that has the effect, whether
directly or indirectly, of mandating particular outcomes or approaches
to reaching a BART determination invades state authority. States do the
cost of compliance and visibility assessments, not EPA. Treating
recommendations as mandates has the effect of forcing all states to
follow each recommendation precisely the same way, effectively
federalizing the BART determination by affording EPA the authority to
employ the SIP approval process as a means of forcing all states to
take the same approach required by EPA in all cases or find their
independent decisions overruled. This violates the structure and design
by Congress, and conflicts with the congressional commitment of the
BART decision to the States. American Corn Growers, 291 F.3d at 7-10.
This problem did not exist when EPA historically construed the
``recommendations'' in the Guidelines to be ``recommendations'' rather
than mandates, but EPA's current approach of identifying deviations
from the CCM or from the ``recommendations'' of the Guidelines as
``errors of law'' destroys state primacy and thus conflicts with the
plain language of the statute and is unreasonable and not entitled to
deference.
EPA's interpretation of the BART Guidelines violates Section 169A
of the CAA because it also restricts state discretion in the decision-
making process. It is the states, not EPA, that are authorized to
determine BART. 42 U.S.C. 7491(b). In doing so they are directed to
take into consideration the five BART factors--costs of compliance,
energy and non-air quality environmental impacts of compliance, any
existing pollution control technology in use at the source, the
remaining useful life of the source, and the improvement in visibility
that would be achieved by the use of control technology. Id. Section
7491(g)(2). The states must determine how to balance these factors, and
how much weight to give each of the factors, on a case-by-case basis.
However, EPA interprets the BART Guidelines as authorizing it to
disapprove the State's BART determination based on alleged technical
failures to follow each and every paragraph and recommendation in the
Guidelines. By relying on isolated instances of alleged deviation from
the Guidelines, such an interpretation totally undermines the State's
prerogative to determine how to weigh and balance all factors and
therefore conflicts directly with the statutory grant of authority to
the states to make BART determinations in accordance with all five BART
factors. Section 169A does not tell the states how to take the factors
into account, nor does it describe how each of the factors must be
treated. The provision directing EPA to provide guidelines to the
states, id. Section 7491(b)(1), must be read in concert with the broad
grant of authority and discretion to states, and does not change the
fundamental thrust of the statute. EPA's interpretation that states are
constrained to dot every ``i'' and cross every ``t'' the way EPA
insists directly conflicts with the statute's grant of BART decision
making authority to the states. If the BART Guidelines mean what EPA
claims they mean, the Guidelines violate the CAA.
Response: As explained elsewhere in this document, we disagree with
the commenter's assertions. The CAA does not give states unlimited
discretion to determine BART; EPA retains the same supervisory role it
has with respect to any SIP submission. We also disagree that our
proposal is inconsistent with the American Corn Growers decision. We
have determined that Wyoming utilized flawed cost assessments and
incorrectly estimated the visibility impacts of controls. We have
determined these issues resulted in non-approvable BART determinations
for the units for which we proposed a FIP. We recognize the State's
broad authority over BART determinations, and recognize the State's
authority to attribute weight and significance to the statutory factors
in making BART determinations. As a separate matter, however, a state's
BART determination must be reasoned and based on an adequate record.
Although we have largely approved the State's regional haze SIP, we
cannot agree that CAA requirements are satisfied with respect to
certain specific BART determinations and other necessary FIP
elements.\62\
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\62\ The commenter cannot challenge EPA's duly promulgated
regulations and Guideline. Indeed, the time for such a challenge has
long passed, since the Guidelines were promulgated July 6, 2005, and
could only have been challenged within 60 days. 70 FR 39,104; 42
U.S.C. 7607(b), (d)(1)(J).
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Comment: The BART Guidelines provide that the ``basis for equipment
costs estimates'' should be documented. Id. at 39166. The Guidelines
give states the option of using ``data supplied by an equipment vendor
(i.e., budget estimates or bids) or by a referenced source (such as the
Cost Manual, fifth Edition, February 1996, EPA 453/B-96-001).'' Id.3.
In footnote language, the Guidelines reiterate that costs should be
documented, including ``any information supplied by vendors that
affects your assumptions regarding purchased equipment costs, equipment
life, replacement of major components, and any other element of the
calculation that differs from the Control Cost Manual.'' Id. at 39167
n.15. EPA relies heavily on this footnote to assert that states,
including Wyoming, have failed to comply with the Guidelines because
they have not adequately documented strict compliance with the CCM.
This is an erroneous and unreasonable interpretation of the Guidelines.
When read in conjunction with the CAA- which bestows substantial
discretion on the states in making BART
[[Page 5087]]
determinations--and other statements made in the BART Guidelines and
the preamble, this footnote language does not require states to supply
vendor quotes or other specific information documenting every single
deviation from the CCM, nor does it confer authority on EPA to reject a
state's BART determination when the state fails to do so. Cf. United
Savings Ass'n v. Timbers of Inwood Forest Assocs., 484 U.S. 365, 371
(1988) (a provision read in isolation ``is often clarified by the
remainder of the statutory scheme . . . because only one of the
permissible meanings produces a substantive effect that is compatible
with the rest of the law''); United States v. Boisdore's Heirs, 49 U.S.
113, 122 (1850) (``[W]e must not be guided by a single sentence or
member of a sentence, but look to the provisions of the whole law, and
to its object and policy.'').
Treating the CCM as a binding checklist conflicts with the CAA,
both in a general sense, by attempting to mandate exactly how a state
must evaluate and apply the five BART factors, and in a specific sense,
by excluding certain costs from consideration in a BART analysis in the
face of statutory language mandating that BART be determined based on
the actual ``costs of compliance,'' not some artificial costs of
compliance. As to the first issue, EPA itself has recognized that the
CCM is ``a good reference tool,'' which can be supplemented ``if there
are elements or sources that are not addressed by the Control Cost
Manual or there are additional cost methods that could be used.'' 70 FR
at 39127. ``States have flexibility in how they calculate costs,''
which is not appropriately circumscribed by recommendations set out in
a non-binding manual. See id. See also id. at 39153 (States retain
discretion in considering ``a number of the factors set forth in
section 169A(g)(2), including the costs of compliance''). As to the
second issue, EPA cannot cite to or rely upon the CCM to challenge any
decision by the states taking into account actual rather than
theoretical costs, because the statute requires that real costs be
considered. CAA Section 169A(g)(2), 42 U.S.C. 7491(g)(2). The CCM does
not impose binding obligations on states undertaking BART
determinations, and failure to comply with its overly general and non-
source specific recommendations is not grounds for rejection of a
state's analysis of the costs of compliance.
Additionally, the CCM has not been subject to notice and comment
under the APA, 5 U.S.C. 701-706; it has not been published in the Code
of Federal Regulations (CFR); and it is not formally incorporated by
reference into the BART Guidelines. Therefore, it is merely a policy
statement that is not binding on the states. Furthermore, simply
referencing the CCM in the BART Guidelines is not adequate to make that
non-binding guidance document legally enforceable. ``Agency statements
`having general applicability and legal effect' are to be published in
the Code of Federal Regulations.'' NRDC v. EPA, 559 F.3d 561, 564 (D.C.
Cir. 2009), citing 1 CFR 8.1(a). See also Brock v. Cathedral Bluffs
Shale Co., 796 F.2d 533, 539 (D.C. Cir. 1986) (``The real dividing
point between regulations and general statements of policy is
publication in the Code of Federal Regulations, which the statute
authorizes to contains only documents `having general applicability and
legal effect . . .' '') (emphasis in original). Accordingly, EPA's
assertion that a state has failed to comply with the BART Guidelines by
using costing methodology other than that set forth in the CCM is
contrary to federal law and is arbitrary and capricious.
Federal regulations require that in order for material to be
formally incorporated by reference into the Federal Register and the
CFR, EPA must seek approval from the Director of the Federal Register.
1 CFR 51.1. Documents are eligible for incorporation only if they meet
certain criteria; incorporation of a document ``produced by the same
agency that is seeking its approval'' is generally inappropriate unless
the Director of the Federal Register finds that the document also
``possess[es] other unique or highly unusual qualities.'' Id. Section
51.7(a)-(b). Furthermore, language incorporating a publication by
reference must be ``as precise and complete as possible,'' including a
statement that the document is ``incorporated by reference'' and
``[i]nform[ing] the user that the incorporated publication is a
requirement.'' Id. Section 51.9(b)(1), (3). Finally, dynamic
incorporations into the CFR are prohibited. Id. Section 51.1(f)
(``Incorporation by reference of a publication is limited to the
edition of the publication that is approved. Future amendments or
revisions of the publication are not included.''). See also 76 FR
33590, 33593 (June 8, 2011) (OSHA noting that ``it cannot incorporate
by reference the latest editions of consensus standards without
undertaking new rulemaking because such action would . . . deprive the
public of the notice-and-comment period required by law'').
EPA has not complied with the requirements for incorporating the
CCM into the regulations directing states to undertake BART
Determinations or into the BART Guidelines. The regulations make no
mention of the CCM. The BART Guidelines reference the CCM, but do not
indicate that EPA was seeking approval for incorporation by reference;
and, in any event, it is unlikely that the CCM meets the requirements
for incorporation by reference. Additionally, the Guidelines reference
the 5th edition of the CCM but direct states to use the most recent
version of the CCM, 70 FR 39167 n.14, and dynamic incorporation is
expressly prohibited by the regulations governing incorporation by
reference, 1 CFR 51.1(f). Where EPA has failed to comply with the
requirements for incorporation by reference, the referenced material is
``ineffective to impose obligations upon, or to adversely affect''
third parties. NRDC v. Train, 566 F.2d 451, 457 (D.C. Cir. 1977).
Therefore, the CCM does not constitute binding law, and EPA has no
authority to reject Wyoming's BART determinations on grounds the State
allegedly strayed from the CCM's cost methodology.
Response: EPA disagrees with this comment. First, with regards to
notice-and-comment procedures, the BART Guidelines, including the
references within them to the Control Cost Manual, have gone through
appropriate public comment procedures and the time to challenge the
BART Guidelines' references to the CCM has passed. If the commenter
believes the BART Guidelines improperly incorporated by reference the
CCM, the commenter could have requested judicial review within 60 days
of the publication of the BART Guidelines in the Federal Register. We
note that the BART Guidelines have indeed been published in the Code of
Federal Regulations, in Appendix Y to Part 51 of Title 40. In addition,
the reference to the CCM in Appendix Y provides adequate notice to the
public that EPA intended the most recent version of the CCM to be used,
and provides a link to the CCM itself.
Moreover, the very action that we are completing today has gone
through notice-and-comment procedures. Thus, the public has had full
opportunity to comment on our application of the CCM. Furthermore, the
commenter's arguments that incorporation by reference is necessary for
anything with binding legal effect miss the mark. The BART Guidelines
do not contain a legally binding requirement to use the CCM, because as
we explain next, the Guidelines clearly state that states may deviate
from the CCM.
Commenter mischaracterizes EPA's use and application of the Control
Cost Manual. EPA's revised cost-effectiveness values are consistent
with
[[Page 5088]]
CAA and RHR requirements. EPA explained in issuing the BART Guidelines
that ``[s]tates have flexibility in how they calculate costs.'' See 70
FR at 39127 (July 6, 2005). A state may deviate from the Control Cost
Manual provided its analysis is reasonable and the deviations are
documented. Here, as discussed elsewhere in this document, Wyoming's
cost-effectiveness values were not reasonable. We disagree with
commenter's view that our cost analysis is improper, but we agree that
the CCM is not the only source of information for the BART analysis.
For instance, the reference to the CCM in the BART Guidelines clearly
recognizes the potential limitations of the CCM and the need to
consider additional information sources:
The basis for equipment cost estimates also should be
documented, either with data supplied by an equipment vendor (i.e.,
budget estimates or bids) or by a referenced source (such as the
OAQPS Control Cost Manual, Fifth Edition, February 1996, EPA 453/B-
96-001). In order to maintain and improve consistency, cost
estimates should be based on the OAQPS Control Cost Manual, where
possible. The Control Cost Manual addresses most control
technologies in sufficient detail for a BART analysis. The cost
analysis should also take into account any site-specific design or
other conditions identified above that affect the cost of a
particular BART technology option.\63\
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\63\ 70 FR 39104, 39166.
As to unusual circumstances, the BART Guidelines call for
``documentation'' to be provided for ``any unusual circumstances that
exist for the source that would lead to cost-effectiveness estimates
that would exceed that for recent retrofits,\64\ which as discussed
elsewhere in this final notice were not provided.
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\64\ 70 FR 39104, 39168.
---------------------------------------------------------------------------
Comment: If EPA is making a BART determination as part of a FIP, it
must comply with the RHR. Section 169A(g)(2) requires the BART
determination to take into consideration five statutory factors. These
factors ``were meant to be considered together'' to arrive at a single
judgment: a BART emission limit. Am. Corn Growers, 291 F.3d at 6. EPA's
proposed FIP, however, does not present a discussion, finding, or
evaluation of the five statutory factors taken together. Instead, EPA
merely states that it proposes to find that Wyoming's BART analysis
fulfills all of the BART requirements except as to cost-effectiveness
and visibility benefits. EPA then proposes to engraft onto Wyoming's
consideration of the five statutory BART factors its own cost-
effectiveness and visibility analysis, to arrive at the conclusion that
SCR is BART. This fails to comply with the statute. The selection of
the BART emission limit is arrived at by considering all five BART
factors taken together. This requires, for example, that the selection
of SCR as BART represents an acceptable balancing of energy and non-air
quality environmental factors. When Wyoming made this assessment,
however, it was considering LNBs and OFA, and thus its conclusion--
which EPA proposes to approve--noted that ``combustion control using
LNB with OFA does not require non-air quality environmental mitigation
for the use of chemical reagents (i.e., ammonia or urea) and there is a
minimal energy impact.'' This weighing of statutory factors does not
discuss or apply SCR, and therefore cannot be adopted by EPA to support
its own BART emissions limit in its FIP. EPA is therefore proposing a
BART emission limit without independently considering the five
statutory BART factors, in violation of Section 169A(g)(2).
Nor does EPA articulate any reasoning supporting its proposed BART
emission limit that applies all of the statutory factors. This violates
EPA's obligation to cogently explain and articulate each step in its
reasoning for proposed action. State Farm, 463 U.S. at 48 (``[A]n
agency must cogently explain why it has exercised its discretion in a
given manner.''). In fact, even as to the cost-effectiveness and
visibility improvements EPA relies upon for its BART emission limit,
EPA states that they are adopted because they are ``in the range of
what EPA has found reasonable for BART in other SIP and FIP actions.''
78 FR 34776. But EPA does not identify which ``actions'' it is talking
about, EPA does not show how the five factors considered in those other
``actions'' make those ``actions'' comparable this action, and EPA does
not pay even minimal lip service to the statutory requirement that
emission limits must be based upon local considerations arrived at by a
careful weighing of statutory factors unique in each case. EPA is just
selecting a preferred technology (SCR) because it considers the cost of
such technology to be acceptable to impose upon Basin Electric, without
regard to whether, when considered for its impacts locally in Wyoming
as Congress intended, it is the ``best'' control option for all of the
circumstances fully considered. This violates five-factor decision-
making process required by the CAA.
Response: We disagree with this comment. Contrary to commenter's
assertions, EPA selected the BART emission limits by considering all
five BART factors taken together and has complied with CAA and RHR
requirements. As discussed in our proposal (see for example discussion
starting at 78 FR 34774) and in our response to comments in this action
(see sections V.B, V.C, and V.D), we clearly consider all five factors.
6. Reasonableness Standard
Comment: EPA cannot sidestep the CAA's mandate for state discretion
by developing and applying a new ``reasonableness'' standard for
evaluating and rejecting that discretion. EPA's regional haze FIP
action, however, does just that. For example, EPA incorrectly declared
``the state's BART analysis and determination must be reasonable in
light of the overarching purpose of the regional haze program.'' (See
78 FR 34743) This overly broad and illegal ``reasonableness'' standard
allows EPA to reject any BART determination that EPA dislikes by merely
arguing that a state's BART determination is ``unreasonable'' and
without comparing the state's determination to any firm or fixed
standards. EPA's ``reasonableness'' standard requires statutory and
regulatory limitations on EPA's authority to disapprove a reasoned RH
SIP. The fallacy of EPA's improper reasonableness standard is made even
more apparent in its application by EPA, which simply rejects as
``unreasonable'' many of Wyoming's BART-related decisions without
offering sufficient justification of why that is the case.
In creating and employing its reasonableness standard, EPA goes to
an even greater extreme by defining ``reasonable'' in the most self-
serving manner imaginable. In short, EPA defines ``reasonable'' to mean
that EPA agrees with the state's exercise of discretion, and it defines
``unreasonable'' to mean EPA does not agree with the state. (See e.g.,
78 FR 34,767, where EPA substitutes its consideration of costs and
visibility improvement for Wyoming's). In this way, EPA attempts to
bootstrap itself into the role of the sole decision-maker of what is
BART and what is not. The CAA does not countenance such overreaching by
EPA. For all of the criticism that EPA makes concerning the state's
analyses, the reality is that the results of the analyses of both
agencies are very similar. In some cases, EPA's numbers (such as the
cost of SNCR at Wyodak) provide less of a justification for EPA's
chosen BART controls than Wyoming's numbers did in its analyses.
However, EPA has used its broad and unjustified criticisms of the
State's work to discredit the State's studies and
[[Page 5089]]
usurp the discretion the State has applied to its BART determinations.
We also received numerous earlier comments pertaining to EPA's use
of a ``reasonableness'' standard for evaluating BART determinations.
For example, commenters pointed out that EPA incorrectly declared ``the
State's BART analysis and determination must be reasonable in light of
the overarching purpose of the regional haze program.'' Commenters
asserted that the fallacy of this improper reasonableness standard is
apparent in its application by EPA, which simply rejects as
``unreasonable'' many of Wyoming's BART-related decisions without
offering a sufficient explanation of why that is the case. Commenters
state that EPA makes no attempt to explain how any of Wyoming's BART
determinations are ``unreasonable,'' but simply decrees that they are
unsupported by any comparison to any standards, regulations, or
statutes.
Commenters argued that the reasonableness standard employed by EPA
is not found in the CAA, the RHR, its Preamble, or Appendix Y.
Commenters go on to point out that nowhere does EPA define or explain
what constitutes ``reasonable in light of the overarching purpose of
the regional haze program'', and that this standard has not been
defined or subjected to notice and comment rulemaking. Commenters
pointed out that the CAA does not authorize EPA to adopt and employ ``a
reasonable in light of the overarching purpose of the regional haze
program'' criterion for approving or disapproving a state BART
determination as CAA Section169A(b)(2)(A) only requires the State to
consider five statutory factors. Commenters asserted that the CAA does
not impose an additional requirement that the final BART determination
is ``reasonable in light of the overarching purpose of the regional
haze program'' as determined by EPA and as such EPA's imposition of
this additional criterion is therefore lacking in statutory authority.
One commenter stated that there are no numerical minimums that emission
rates much achieve in a BART determination and there are no statutory
minimum ``visibility improvement'' obligations.
One commenter went on to point that the failure to define how it
will determine reasonableness leads to inconsistent and subjective
agency action, as illustrated by EPA's inconsistent treatment of BART
decisions around the country. The commenter pointed to BART decisions
in Oklahoma, North Dakota, and Nevada as examples where EPA's failure
to define reasonableness has led to inconsistent BART decisions.
Another commenter argued that throughout its proposal, EPA claims
to have reviewed Wyoming's SIP under a ``reasonableness'' standard.
See, e.g., 78 FR 34776 (``we do not consider Wyoming's analyses . . .
to be reasonable''); see also id. at 34778. EPA apparently believes
that this standard allows EPA to substitute its judgment for the
State's whenever EPA generally alleges that the State's conclusions or
methods are not reasonable. Yet EPA cites no statutory or regulatory
authority to support its malleable application of this
``reasonableness'' standard of review. EPA appears to have crafted its
flexible reasonableness standard from Alaska Department of
Environmental Conservation v. EPA, 540 U.S. 461 (2004). That case
stands for the proposition that EPA has authority to reject a state
decision that ``is not based on a reasoned analysis[.]'' Id. at 490
(internal quotation omitted). EPA has misapplied that standard in its
proposal to disapprove Wyoming's SIP.
The commenter further argued that the ADEC standard does not allow
EPA to disapprove SIPs whenever, in EPA's opinion, some element of the
SIP is not reasonable. Instead, EPA must provide SIPs ``considerable
leeway'' and may not ``second guess'' state decisions[.]'' ADEC, at 490
(internal citation omitted). Accordingly, EPA may disapprove a SIP
under ADEC only by showing that the SIP is arbitrary. See id. at 490-
91. EPA therefore must defer to the Wyoming's determinations in the
SIP, and may not simply substitute its judgment for the State's. And,
of course, EPA carries the burdens of production and persuasion to show
that the State acted unreasonably in light of the statutes and
administrative record. Id. at 494.
The commenter asserted that EPA has failed to carry those burdens
in its proposed partial disapproval of Wyoming's regional haze SIP. The
administrative record demonstrates that Wyoming's SIP will achieve the
statutory goal of reasonable progress. EPA has not shown otherwise. EPA
has shown only that if it had crafted the implementation plan in the
first instance, it would have done so differently than Wyoming did. But
the law does not allow EPA to simply substitute EPA's preferences for
the State's. Before EPA can disapprove the SIP, it must show that the
SIP is arbitrary, in light of the statutes and the record, and with
consideration for the deference owed the State's determinations. For
example, with respect to Jim Bridger Units 1 and 2 the only meaningful
difference in outcomes between EPA's proposed FIP and the SIP is a
roughly five-year period in which EPA's proposed controls will result
in lesser emissions, though without a perceptible visibility
improvement. Save for this distinction, the SIP and FIP create
essentially equal improvements in visibility. EPA does not explain why
a reduction in NOX emissions that is more expensive but not
more effective at improving visibility is more reasonable than the SIP.
That lack of explanation renders EPA's proposal arbitrary, and
decidedly ``unreasonable.''
Response: EPA disagrees with this comment. The CAA requires states
to submit SIPs that contain such measures as may be necessary to make
reasonable progress toward achieving natural visibility conditions,
including BART. The CAA accordingly requires the states to submit a
regional haze SIP that includes BART as one necessary measure for
achieving natural visibility conditions. In view of the statutory
language, it is logical that the reasonableness of the State's BART
analysis and determination would be evaluated in light of the purpose
of the regional haze program. In addition, our regional haze
regulations, at 40 CFR 51.308(d)(ii), provide that when a state has
established a RPG that provides for a slower rate of improvement in
visibility than the URP (as has Wyoming), the state must demonstrate,
based on the reasonable progress factors--i.e., costs of compliance,
time necessary for compliance, energy and non-air quality environmental
impacts of compliance, and remaining useful life of affected sources--
that the URP to attain natural visibility conditions by 2064 is not
reasonable and that the progress goal adopted by the state is
reasonable. 40 CFR 51.308(d)(iii) provides that, ``in determining
whether the State's goal for visibility improvement provides for
reasonable progress towards natural visibility conditions, the
Administrator will evaluate'' the state's demonstrations under section
51.308(d)(ii). It is clear that our regulations and the CAA require
that we review the reasonableness of the State's BART determinations in
light of the goal of achieving natural visibility conditions. This
approach is also inherent in our role as the administrative agency
empowered to review and approve SIPs. Thus, we are not establishing a
new reasonableness standard, as the commenter asserts. As we discuss
elsewhere, ADEC supports the use of this standard, and does not require
EPA to apply a sort of ``arbitrary and
[[Page 5090]]
capricious'' standard in reviewing Wyoming's SIP submittal. The
language regarding the burdens of production and persuasion in ADEC are
inapplicable, as they refer to a litigation context that is not present
here.
Furthermore, this is a SIP review action, and we believe that EPA
is not only authorized, but required to exercise independent technical
judgment in evaluating the adequacy of the State's regional haze SIP,
including its BART determinations, just as EPA must exercise such
judgment in evaluating other SIPs. In evaluating other SIPs, EPA is
constantly exercising judgment about SIP adequacy, not just to meet and
maintain the NAAQS, but also to meet other requirements that do not
have a numeric value. In this case, Congress did not establish NAAQS by
which to measure visibility improvement; instead, it established a
reasonable progress standard and required that EPA assure that such
progress be achieved. Here, contrary to the commenter's assertion, we
are exercising judgment within the parameters laid out in the CAA and
our regulations. Our interpretation of our regulations and of the CAA,
and our technical judgments, are entitled to deference. See, e.g.,
Michigan Dep't. of Envtl. Quality v. Browner, 230 F.3d 181 (6th Cir.
2000); Connecticut Fund for the Env't., Inc. v. EPA, 696 F.2d 169 (2nd
Cir. 1982); Voyageurs Nat'l Park Ass'n v. Norton, 381 F.3d 759 (8th
Cir. 2004); Mont. Sulphur & Chem. Co. v. United States EPA, 2012 U.S.
App. LEXIS 1056 (9th Cir. Jan. 19, 2012).
Finally, regarding commenters' assertions that we are being
inconsistent, because the comment is not specific about what aspect of
our proposed disapproval is believed to be inconsistent with other EPA
decisions, it is not possible for EPA to address in this response any
specific concerns. As articulated in our proposed rulemaking and
further explained in our responses to other comments, EPA's partial
approval and partial disapproval of the Wyoming regional haze SIP is
consistent with the CAA, the RHR, BART Rule, and EPA guidance.
Comment: In the absence of criteria or standards by which
``reasonableness'' may be assessed, EPA's claim that the State's BART
for Laramie River Station is unreasonable is by definition a mere
subjective conclusion without basis or foundation. EPA must instead
articulate a standard grounded in the statute by which it evaluates and
disapproves a SIP and then must support its decision with a plausible
explanation connecting the facts to its standard.
Response: The CAA requires states to submit SIPs that contain such
measures as may be necessary to make reasonable progress toward
achieving natural visibility conditions, including BART. The CAA
accordingly requires the states to submit a regional haze SIP that
includes BART as one necessary measure for achieving natural visibility
conditions. In view of the statutory language, it is reasonable for the
State's BART analysis and determination to be evaluated in light of the
purpose of the regional haze program.
In addition, our regional haze regulations, at 40 CFR
51.308(d)(ii), provide that when a state has established a RPG that
provides for a slower rate of improvement in visibility than the URP
(as has Wyoming), the state must demonstrate, based on the reasonable
progress factors--i.e., costs of compliance, time necessary for
compliance, energy and non-air quality environmental impacts of
compliance, and remaining useful life of affected sources--that the
rate of progress to attain natural visibility conditions by 2064 is not
reasonable and that the progress goal adopted by the state is
reasonable. 40 CFR 51.308(d)(iii) provides that, ``in determining
whether the State's goal for visibility improvement provides for
reasonable progress towards natural visibility conditions, the
Administrator will evaluate'' the state's demonstrations under section
51.308(d)(ii). Therefore, it is clear that our regulations and the CAA
require that we review the reasonableness of the State's BART
determinations in light of the goal of achieving natural visibility
conditions. This approach is also inherent in our role as the
administrative agency empowered to review and approve SIPs. Thus, we
are not establishing a new reasonableness standard, as the commenter
asserts.
Here, Wyoming concluded that a limit of 0.21lb/MMBtu for Laramie
River Station could be achieved with operation of LNBs with OFA. As
presented in the Introduction section and elsewhere in the notice, the
State's regional haze SIP determined that NOX BART for
Laramie River Units 1, 2, and 3 is new LNB/SOFA. We proposed to
disapprove the State's determination because the State did not
reasonably assess the costs of compliance and visibility improvement in
accordance with the BART Guidelines. 78 FR 34766. After revising the
State's costs and modeling and re-evaluating the statutory factors, we
proposed to determine that NOX BART is LNB/SOFA + SCR, with
an emissions limit of 0.07 lb/MMBtu for each unit. As the result of the
comments received on our proposal, we have further revised our
calculation of the costs of compliance and visibility modeling. For
example, as explained in the BART section of this document, we
corrected cost estimates for elevation and provided detailed comments
regarding how site characteristics were addressed using available
satellite imagery and why this is a valid approach for providing
estimates that are acceptable for BART analysis and consistent with CAA
and regulations. While we accepted some of the revised costs, again as
explained in the BART section of this document, we did not accept
others. For example, we did not accept cost assumptions where the
necessary supporting documentation was not provided. After re-
evaluating the BART factors, we continue to find that LNB/SOFA + SCR is
reasonable as BART and are therefore finalizing our proposal. As a
result, we are finalizing our proposed disapproval of the State's
NOX BART determination for Laramie River Station and
finalizing our proposed FIP that includes a NOX BART
determination of LNB/SOFA + SCR, with an emission limit of 0.07 lb/
MMBtu (30-day rolling average). The facts presented here and elsewhere
in our final notice, provided a basis and foundation, grounded on the
CAA and regulations, for the EPA to reach its decision regarding the
unreasonableness of Wyoming's BART for Laramie River Station.
Comment: EPA attempted to use post-hoc, immaterial changes that it
calculated in costs and visibility improvements to justify usurping
Wyoming's BART decision-making authority. This runs counter to the vast
discretion EPA has given to other states' regional haze SIPs. In
Oregon, for example, despite EPA and Oregon differing in how each
calculated BART costs that resulted in cost variance of over $700 per
ton, EPA stated that such difference between the two estimates would
not materially affect Oregon's evaluation. The difference between the
cost analyses under EPA's FIP action and the Wyoming regional haze SIP
similarly is immaterial. Similarly, in Colorado, the State's plan
included a cost analysis that, according to EPA, was not conducted in
accordance with EPA's Control Cost Manual. In addition, EPA explained
that Colorado should have more thoroughly considered the visibility
impacts of controlling emissions from one BART unit on the various
impacted Class I areas and not focused on just the most impacted Class
I area. Nevertheless, EPA approved the State's SIP, explaining that
``Colorado's
[[Page 5091]]
plan achieves a reasonable result overall.'' EPA should afford Wyoming
the same degree of deference it afforded Colorado and Oregon. As
demonstrated by the impacts of the Wyoming SIP, it ``achieves a
reasonable result overall.''
EPA's inconsistency is not just limited to its disparate actions
between states. In Wyoming, EPA acted inconsistently in its BART
determinations between sources within the state. For example, EPA
accepted Wyoming's cost and visibility BART analyses for FMC Westvaco
and General Chemical, along with the PM BART analyses for PacifiCorp's
and Basin Electric's BART units. At the same time, EPA rejected the
NOX BART cost and visibility analyses for PacifiCorp's and
Basin Electric's BART units. Wyoming, however, used the same BART
analysis methodology for those BART units at which EPA accepted the
Wyoming BART analysis as it did at those BART units for which EPA did
not. By rejecting some cost and visibility analyses on the basis that
they were improperly performed, while accepting others that were
performed in the same manner, EPA acted arbitrarily and capriciously.
Response: We disagree with this comment. In evaluating a State's
BART determination, EPA has the discretion to develop additional
information, such as cost and visibility analyses. In the end, this
additional information, may confirm the State's BART determination as
reasonable, or it may lead EPA to disapprove the State's BART
determination as unreasonable. However, EPA is not required to develop
additional information for all BART determinations in order to review
the State's BART determination. If a State's BART determination appears
to have reached a reasonable conclusion, taking into account existing
information and the potential magnitude or effect of technical flaws in
cost or visibility analyses, EPA may approve the BART determination.
However, if the potential technical flaws in analyses make it possible
that the State's BART determination would be unreasonable, then EPA may
develop additional information to try to determine whether the State's
BART determination would fall within the range of reasonable outcomes
using proper technical analyses. For example, as we explain elsewhere
in responding to comments on modeling, in this action EPA was unable to
ascertain the visibility benefits of individual NOX controls
for the PacifiCorp units from the State's modeling because the emission
reductions for multiple pollutants were modeled together, and therefore
we were unable to assess the reasonableness of the State's BART
determinations.\65\ Similarly, for the Basin Electric units, we were
unable to ascertain the visibility benefits of SNCR. For that reason,
we developed additional modeling. In some cases, the additional
modeling confirmed the reasonableness of the State's decisions while in
others it did not.
---------------------------------------------------------------------------
\65\ As we explain later in this document ``[t]hat is, since the
visibility improvement for each of the State's control scenarios was
due to the combined emission reductions associated with
SO2, NOX, and PM controls, it was not possible
to isolate what portion of the improvement was attributable to the
NOX controls alone. For this reason, in the modeling
conducted by EPA, we held SO2 and PM emission rates
constant (reflecting the ``committed controls'' for those pollutants
identified by Wyoming), and varied only the NOX emission
rate. This allowed us to isolate the degree of visibility
improvement attributable to the NOX control option.'' See
response to comments in the modeling section for further
information.
---------------------------------------------------------------------------
With respect to the State's PM BART determinations, the dollar per
ton costs for higher-than-current levels of control were generally high
(regardless of potential flaws in determining those costs), so existing
information was adequate to find that the PM BART determinations were
reasonable. With respect to FMC Westvaco and General Chemical, the
State's modeling (which as we discuss elsewhere used a conservative
estimate of background ammonia which would tend to result in an
overestimation of visibility impacts) showed fairly low visibility
benefits from NOX controls. Based on consideration of the
five BART factors, the State selected combustion controls for these
BART sources. EPA also finds these determinations reasonable, and EPA
has no reason (nor does the commenter provide one) to think otherwise.
With respect to the comments regarding Oregon and Colorado,
although consistency with similar determinations is one hallmark of
reasonableness, the BART determinations are very fact-specific and
cannot be easily compared across states. For example, in the Oregon
action, EPA noted that (among other things) the source would shutdown
in 2020, so ``it [was] reasonable for the state to consider the sizable
capital cost difference between [two technologies], and the relatively
small incremental visibility improvement between the two
technologies.'' 76 FR 38900. Thus, EPA could assess on the basis of
existing information that the State's BART determination was
reasonable. With respect to the Colorado SIP, we disagree with the
commenter that the Wyoming and Colorado SIPs would achieve comparable
visibility improvement.
With respect to consistency generally, in this action we have
considered the five factors in the context of each facility. Although
one factor (such as visibility improvement or costs of compliance) may
be similar for a unit in another state, each factor must be weighed in
the context of the other source-specific BART factors.
Comment: Section 169A(g)(2) of the CAA requires states, in
determining BART, to ``take into consideration the costs of compliance,
the energy and non-air quality environmental impacts of compliance, any
existing air pollution control technology in use at the source, the
remaining useful life of the source, and the degree of visibility
improvement which may reasonably be anticipated to result from the use
of such technology.'' 42 U.S.C. 7491(g)(2). The CAA does not require
the achievement of any specific degree of visibility improvement, and
only requires that a BART determination eliminate or reduce impairment
to visibility. See id. Section 7491. If the state's determination does
so, the state has complied with the statute and nothing authorizes EPA
to propose or impose its own BART decision.
EPA's proposed action, however, articulates a number of additional
grounds that must be met for a SIP to be ``approvable.'' These
additional grounds are not found in the text of the CAA and have never
been defined or promulgated with notice and comment rulemaking. For
example, EPA's proposed action articulates a two pronged test for BART
SIP approval: First, ``a state must meet the requirements of the CAA
and our regulations for selection of BART''; and then second, ``the
state's BART analysis and determination must be reasonable in light of
the overarching purpose of the regional haze program.'' 78 FR 34743.
Basin Electric has no problem with the first prong of this test,
i.e., that a state's SIP must ``meet the requirements of the CAA'' and
``any [applicable] regulations''--so long as those regulations are
confined to the areas Congress allowed EPA to regulate. However, the
second prong, i.e., that ``the State's BART analysis and determination
must be reasonable in light of the overarching purpose of the regional
haze program,'' sets out a new ``reasonableness'' obligation that is
neither defined in nor separately set forth in the Act. Essentially,
EPA is proposing to measure a BART determination not just against the
statutory criteria but also against EPA's own subjective view whether
the result reached is reasonable enough to meet
[[Page 5092]]
the ``overarching goal'' of the Act. But since EPA acknowledges that
neither the Act nor the regulations ``mandate specific milestones or
rates of progress,'' 76 FR 58577, EPA's subjective reasonable enough
requirement imposes a new legislative standard that either goes beyond
or, for the first time, purports to define ``the requirements of the
Act.'' This empowers EPA to disapprove a state BART determination and
replace it with its own on reasonableness grounds that have never been
defined or vetted through public notice and comment.
The same is true with EPA's assertion that Wyoming did not provide
``sufficient documentation.'' 78 FR 34749. EPA is asserting the
existence of, and then a failure to meet, a ``sufficient
documentation'' requirement that is both undefined and entirely of
EPA's own creation. This allows EPA to extend its regulatory reach to
determine and impose its own view of BART when a state's reasoning,
according to EPA, fails to meet unannounced and undefined legislative
criteria. Such an expansion of EPA's substantive powers is illegal. EPA
may not employ evaluative criteria that effectively extend or define
the reach of the CAA without first subjecting those criteria to public
notice and comment. See, e.g., Syncor Int'l Corp. v. Shalala, 127 F.3d
90, 95-96 (D.C. Cir. 1997) (requiring the FDA to subject a rule that
extended its regulatory reach to notice and comment before applying
it); U.S. Tel. Ass'n v. FCC, 28 F.3d 1232, 1233-34 (D.C. Cir. 1994)
(finding that the FCC's application of a new standard was a substantive
rule requiring notice and comment); Am. Mining Congress v. Mine Safety
& Health Admin., 995 F.2d 1106, 1112 (D.C. Cir. 1993) (outlining the
factors to apply in determining when a rule is substantive and thus
requires notice and comment).
As the D.C. Circuit Court has explained, when an agency implements
a substantive change to its regulations that alters the boundaries of
what the agency can regulate, the change must be subject to public
notice and comment so that an agency does not expand its power without
public involvement. Appalachian Power Co. v. EPA, 208 F.3d 1015, 1024
(D.C. Cir. 2000). The same is true when EPA purports, for the first
time, to vet a state SIP revision against criteria of its own making
not set forth in the governing statute or the existing regulations.
Here, EPA is effectively stating that: (1) The most cost-effective (on
a dollar per ton basis) control technology must be selected as BART;
(2) a state BART determination must be ``adequately justified,''
``sufficiently documented,'' and ``properly made''; and (3) the state's
determination must meet EPA's subjective view of ``reasonableness'' in
reaching the non-binding goal of the regional haze Program. Each of
these new criteria is outcome determinative, according to EPA, and each
must be met for the State to be considered in compliance with Section
169A. As such, these are new legislative rules that cannot be adopted
and imposed without first being submitted to notice and comment
rulemaking as required by CAA Section 307(d), 4207 U.S.C. 7607.
An important indicator of when public notice is required is that
the change would allow the agency to extend its own power: ``[A]
substantive rule modifies or adds to a legal norm based on the agency's
own authority . . . And, it is because the agency is engaged in
lawmaking that the APA requires it to comply with notice and comment.''
Syncor, 127 F.3d at 95 (emphasis in original). EPA's current proposal
to disapprove Wyoming's BART determination does exactly that. EPA uses
its own authority to modify the legal norm for reviewing State BART
decisions to give itself the ultimate authority to impose its own
favored BART standards.
The need for advance rulemaking is particularly acute when EPA
interprets and applies a statute that itself establishes no concrete,
objective requirements. No specific rates of progress, technologies, or
visibility improvements are mandated by the RHR. Unlike review of a
SIP, where EPA applies specifically defined ambient concentrations to
determine if the SIP should be approved, there are no objective
criteria against which to measure the ``reasonableness'' of any state
BART determination with respect to cost and visibility judgments.
Under EPA's self-defined standards, EPA is left with unfettered
discretion to disapprove any decision with which it disagrees on the
grounds that it is not ``reasonable'' enough to meet EPA's preferences.
This is why the law requires EPA to first define and promulgate rules
explaining what is ``reasonable'' enough, or what is ``sufficiently
documented'' enough, to support a BART determination. Otherwise, EPA
can trump state discretion on the basis of internally conceived and
unexamined evaluative criteria that extend EPA's reach without public
involvement.
Response: EPA disagrees with this comment. First, even assuming
that EPA's proposed action on the Wyoming regional haze SIP articulated
new grounds for evaluating a regional haze SIP, the proposed action
provides the public with the opportunity to comment. As evidenced by
the commenter's submission, the commenter had the opportunity to
comment on EPA's approach to evaluating the Wyoming regional haze SIP
and to identify any concerns associated with the statement at issue
from our proposal and other aspects of our action.
Second, the CAA requires states to submit SIPs that contain such
measures as may be necessary to make reasonable progress toward
achieving natural visibility conditions, including BART. The CAA
accordingly requires the states to submit a regional haze SIP that
includes BART as one necessary measure for achieving natural visibility
conditions. In view of the statutory language, it is reasonable that
the State's BART analysis and determination would be evaluated in light
of the purpose of the regional haze program. In addition, our regional
haze regulations, at 40 CFR 51.308(d)(ii), provide that when a state
has established a RPG that provides for a slower rate of improvement in
visibility than the URP (as has Wyoming), the state must demonstrate,
based on the reasonable progress factors--i.e., costs of compliance,
time necessary for compliance, energy and non-air quality environmental
impacts of compliance, and remaining useful life of affected sources--
that the rate of progress to attain natural visibility conditions by
2064 is not reasonable and that the progress goal adopted by the state
is reasonable. 40 CFR 51.308(d)(iii) provides that, ``in determining
whether the State's goal for visibility improvement provides for
reasonable progress towards natural visibility conditions, the
Administrator will evaluate'' the state's demonstrations under section
51.308(d)(ii). It is clear that our regulations and the CAA require
that we review the reasonableness of the State's BART determinations in
light of the goal of achieving natural visibility conditions. This
approach is also inherent in our role as the administrative agency
empowered to review and approve SIPs. Thus, we are not establishing a
new reasonableness standard, as the commenter asserts.
As explained above, our proposal clearly laid out the bases for our
proposed disapproval of the State's BART and reasonable progress
determinations, and we have relied on the standards contained in our
regional haze regulations and the authority that Congress granted us to
review and determine whether SIPs comply with
[[Page 5093]]
the minimum statutory and regulatory requirements. In determining SIP
adequacy, we inevitably exercise our judgment and expertise regarding
technical issues, and it is entirely appropriate that we do so. Courts
have recognized this necessity and deferred to our exercise of
discretion when reviewing SIPs.
Finally, we disagree with the argument that we must approve a BART
determination where the SIP reflects consideration of the five factors
and the BART selection will result in some improvement in visibility.
We think Congress expected more when it required the application of
``best available retrofit technology.''
Comment: In 2004, EPA represented to the United States Supreme
Court that it would act only very rarely to overrule a state decision
selecting control technology for specific sources. ADEC. Relying upon
this representation to rebut doubts expressed by the dissent, the
Supreme Court affirmed EPA's decision to overrule a BACT decision made
by the State of Alaska on the grounds that the State's decision was not
``reasonable'' because the record lacked the information necessary to
support the State's cost assessment. The ADEC Court held that EPA could
review state BACT determinations to ascertain whether they were
``reasonable in light of the statutory guides and the state
administrative record.'' Id. at 494.
EPA now relies upon the Supreme Court's use of the word
``reasonable'' in the BACT context to assume authority to judge the
``reasonableness'' of state BART decisions when reviewing SIP revisions
under Section 110, and thus to disapprove any BART determination it
considers ``unreasonable'' ``in light of the over-arching purpose of
the regional haze program.'' 78 FR 34743. This formulation seriously
misconstrues and misstates the Supreme Court's holding and runs counter
to the CAA's conferral of authority on the State in selecting BART.
``Reasonableness in EPA's subjective view'' cannot be applied as a
rubric for approving state BART decisions, as it allows EPA to impose
its own BART preferences. Rather than adhere to the core principles of
cooperative federalism codified in the RHR by only rarely overruling
state technology choices, EPA instead does exactly what it represented
to the Supreme Court it would not do--routinely overrule state
determinations--and it does so under the rubric of authority to
evaluate ``reasonableness'' on a subjective basis.
Examination of EPA's action in this and related BART proceedings
around the country demonstrates that EPA is not using the
``reasonableness'' standard that was actually approved in ADEC. Far
from endorsing a generic ``reasonableness in EPA's view'' standard, the
ADEC Court echoed the language of APA arbitrary and capricious review
and upheld EPA's rejection of a State BACT determination on grounds
that the State's determination was not supported by the administrative
record. The Court stated that ``[o]nly when a state agency's BACT
determination is `not based on a reasoned analysis' may EPA step in to
ensure that the statutory requirements are honored,'' and that the Act
``authorizes EPA to act in the unusual case in which a state permitting
authority has determined BACT arbitrarily.'' 540 U.S. at 490-91;
citation omitted). The Court added that ``EPA adhered to that limited
role here, explaining why ADEC's BACT determination was `arbitrary' and
contrary to [the State]'s own findings.'' Id. The Court thus held that
EPA had properly exercised its authority to reject the State's BACT
determination when the State switched from an initial finding that a
certain technology was economically feasible to finding that the same
technology was economically infeasible with ``no factual basis in the
record'' to support the change. Id. at 496-500.
Here, EPA makes no effort to formulate and apply a
``reasonableness'' standard that appropriately preserves for EPA only
the ``limited role'' of insuring that a state decision is not arbitrary
and capricious and lacking in record support. Instead, EPA scours the
record for inconsequential actions taken by states which it can portray
as ``inconsistent with'' the massively complex, out-dated, and non-
binding CCM or with the largely advisory Guidelines so that EPA can
declare the state's decision to be ``unreasonable'' and take over the
choice of BART technology. EPA does not demonstrate any arbitrary or
capricious conduct, any lack of reasoned decision making, or any other
documented failure by the State to follow the requirements of the
statute, as contemplated by the standard actually approved in ADEC. As
a result, EPA is not employing the ``reasonableness'' test properly,
and with that error is arrogating power Congress left to the States,
precisely as predicted by the ADEC dissent. In state after state, EPA
is now striking down state BART decisions and cloaking its disregard
for state primacy by adjudging those decisions as ``unreasonable,''
purportedly in reliance upon authority granted by ADEC. But it strains
credulity for EPA to assert that state after state is making
essentially the same repeated arbitrary and capricious decisions, the
remedy for which is almost always mandatory imposition by EPA of its
preferred technology choice: SCR. EPA's ``reasonableness'' test is
therefore fundamentally erroneous. EPA may not exercise authority ``in
a manner that is inconsistent with the administrative structure that
Congress enacted into law,'' ETSI Pipeline Project, 484 U.S. at 517, by
applying a subjective reasonableness standard to federalize BART
decisions.
Response: We responded to similar comments elsewhere in this
document.
Comment: Because EPA's proposed disapproval of Wyoming's BART
determination for Laramie River Station is inconsistent with EPA's
prior approval of other state BART choices, EPA's proposed decision is
an abuse of discretion and not entitled to deference from a reviewing
court.
For instance, in a CAA case involving EPA approval of state Title V
programs, the Ninth Circuit reversed EPA's disapproval of one state's
program where EPA's decision ``conflict[ed] substantially with numerous
EPA decisions in other states and localities.'' W. States Petroleum, 87
F.3d at 282. In that case, EPA had conditioned final approval of
Washington's proposed Title V program on the State's repeal of certain
insignificant emissions units (``IEU'') exemptions. EPA eventually
approved the State's Title V program, but disapproved the IEUs
exemptions as inconsistent with the applicable regulations. Id. at 283.
Industry members and the State challenged EPA's disapproval on the
basis that EPA's decision was inconsistent with its prior
interpretation and application of the regulations in other states. Id.
at 282-83. Specifically, EPA had condoned the exemption of IEUs from
the permit content requirements of the regulations in at least eight
other state and local programs. Id. at 283. Based on this evidence, the
Ninth Circuit held that EPA's rejection of Washington's IEU rules was
``undeniably a change in agency interpretation.'' Id. at 284.
Accordingly, EPA was required to support its change by ``reasoned
analysis,'' which it did not do. Id. (EPA ``may not depart, sub
silentio, from its usual rules of decision to reach a different,
unexplained result in a single case''). The court held that EPA abuses
its discretion where it approves numerous state programs that include
the very same aspects forming the basis for EPA's denial of another
state's program. Id. at 285.
[[Page 5094]]
Other courts have similarly expressed that an agency acts
arbitrarily and capriciously when it departs from prior interpretations
or precedent without adequately explaining the reasons for its
departure. See, e.g., Cnty. of Los Angeles v. Shalala, 192 F.3d 1005,
1022 (D.C. Cir. 1999) (``A long line of precedent has established that
an agency action is arbitrary when the agency offer[s] insufficient
reasons for treating similar situations differently.''); Shaw's
Supermarkets, Inc. v. N.L.R.B., 884 F.2d 34, 41 (1st Cir. 1989)
(``Unless an agency either follows or consciously changes the rules
developed in its precedent, those subject to the agency's authority
cannot use its precedent as a guide for their conduct; nor will that
precedent check arbitrary agency action.''); Puerto Rican Cement Co. v.
EPA, 889 F.2d 292, 298 (1st Cir. 1989) (noting ``the well-established
legal doctrine that an agency `must either follow its own precedents or
explain why it departs from them' '') (citation omitted); Int'l
Internship Programs v. Napolitano, 853 F. Supp.2d 86, 94 (D.D.C. 2012)
(``[I]f an agency adopts `a new position inconsistent with' an existing
regulation, or effects `a substantive change in the regulation,' the
agency must comply with the notice and comment requirements of the
APA.'') (citation omitted). Moreover, consistency is a factor to be
weighed in determining how much deference an agency's interpretation is
entitled to receive. Good Samaritan Hosp. v. Shalala, 508 U.S. 402, 417
(1993) (``[T]he consistency of an agency's position is a factor in
assessing the weight that position is due.''). When an ``Agency's
regulations reflect the Agency's own longstanding interpretation,'' a
court ``will normally accord particular deference'' to such
``interpretation of `longstanding' duration.'' Barnhart v. Walton, 535
U.S. 212, 219-20 (2002). But ``the case for judicial deference is less
compelling with respect to agency positions that are inconsistent with
previously held views.'' Pauley, 501 U.S. at 698. ``An agency
interpretation of a relevant provision which conflicts with the
agency's earlier interpretation is `entitled to considerably less
deference' than a consistently held agency view.'' I.N.S. v. Cardoza-
Fonseca, 480 U.S. 421, 446 n.30 (1987). See also Watt v. Alaska, 451
U.S. 259, 273 (1981) (``The Department [of Interior]'s current
interpretation, being in conflict with its initial position, is
entitled to considerably less deference.''); W. States Petroleum, 87
F.3d at 285 (the court ``need not defer to the EPA because the EPA has
abused its discretion in departing from its own prior standards'').
Here, EPA has taken an inconsistent approach in interpreting the
RHR, the Guidelines, and the CCM. In particular, EPA's current
interpretation of its role and the states' role under these provisions
conflicts with its prior, long-held understanding that states serve the
primary role in determining BART and that EPA should not interfere with
the many judgments that go into making BART determinations.
More specifically, EPA's application of its improper and subjective
``reasonableness'' standard when reviewing BART determinations in the
SIP approval process has yielded inconsistent, and therefore arbitrary
and capricious, results. Here, EPA identifies what it describes as
``cost and visibility errors for EGUs'' in Wyoming's SIP sufficient to
permit EPA to disapprove the BART determination for Laramie River, yet
EPA proceeds to approve other Wyoming BART decisions as ``reasonable''
``despite the[se] . . . errors.'' 78 FR 34750. Either EPA is applying
the law arbitrarily and capriciously, or it is simply approving as
``reasonable'' only those choices with which it agrees, either of which
is erroneous. EPA must be reasonably consistent in reviewing state BART
determinations.
Response: We responded to similar comments above.
Comment: EPA's implementation of the RHR does not satisfy the CAA's
requirements of consistency. The conclusions reached by EPA on similar
issues vary from case to case in ways that cannot be explained by
statute, regulation, or guiding principle. EPA seems to act on BART
determinations with an eye towards achieving its desired outcome rather
than implementing the CAA even-handedly. This is the definition of
caprice. States, regulated entities, and the public are left guessing
as to what will be required in any given case. Because EPA has been so
inconsistent in the current case and in its overall administration of
the RHR, its proposal to disapprove Wyoming's BART determinations for
Laramie River and to impose a FIP is arbitrary and capricious and must
be abandoned.
Response: We responded to similar comments above.
7. Reliance on Emission Reductions
Comment: EPA's regional haze FIP action is also illegal, arbitrary,
and capricious because it relies upon factors outside of the BART five-
factor analysis. Nowhere in the five-factor analysis, or anywhere in
the Appendix Y Guidelines, is there any support for EPA using an
``emissions reduction'' factor. But this is exactly what EPA has done
in its FIP. For example, EPA cited ``emission reductions'' as the basis
for the FIP BART NOX decisions for Dave Johnston Unit 3 (See
77 FR 33052), Wyodak (See 77 FR 33055) and Laramie River (See 77 FR
33001), among others. In doing so, however, EPA failed to account for
the fact that the regional haze program is not an emissions reduction
program per se, but is a visibility improvement program.
Additionally, it is improper for EPA to reject Wyoming's BART
determinations, which relied upon the proper balancing of all five BART
factors, and replace those BART determinations with EPA's analysis,
which relied upon factors outside the five-factor analysis, such as
emissions reductions. (See e.g., 77 FR at 33,052.) Courts have held
that when an agency relies on factors ``which Congress has not intended
it to consider,'' then such action is arbitrary and capricious. Arizona
Public Service Co. v. US EPA, 562 F.3d 1116, 1123 (10th Cir. 2009).
Earlier comments asserted that EPA's regional haze FIP is also
illegal, arbitrary, and capricious because it relies upon factors
outside of the BART five-factor analysis. Nowhere in the five-factor
analysis, or anywhere in Appendix Y, is there any support for EPA using
an ``emissions reduction'' factor. But this is exactly what EPA has
done. For example, EPA cites ``emission reductions'' as the basis for
the regional haze FIP BART NOX decisions for Dave Johnston
Unit 3, Wyodak, and Laramie River Station, among others. In doing so,
however, EPA fails to account for the fact that the regional haze
program is not an emissions reduction program per se, but is a
visibility improvement program.
EPA's over-reliance on ``emissions reductions'' outside of the
mandated BART factors has caused EPA to overstep the boundaries of the
regional haze program. This is evidenced by the virtually non-existent
visibility improvements associated with SNCR at Wyodak and Dave
Johnston that EPA approved because of the associated emission
reductions. Additionally, it is improper for EPA to reject Wyoming's
BART determinations, which relied upon the proper balancing of all five
BART factors, and replace those BART determinations with EPA's
analysis, which relied upon factors outside the five-factor analysis.
Courts have held that when an agency relies on factors ``which Congress
has not intended it to consider,'' then such action is arbitrary and
capricious. Arizona Public Service
[[Page 5095]]
Co. v. US EPA, 562 F.3d 1116, 1123 (10th Cir. 2009).
Response: We disagree with the commenter's characterization of the
role of emission reductions in the BART analyses. The RHR provides
that:
The determination of BART must be based on an analysis of the
best system of continuous emission control technology available and
associated emission reductions achievable for each BART-eligible
source that is subject to BART * * * \66\
---------------------------------------------------------------------------
\66\ 40 CFR 51.308(e)(1)(ii)(A).
Thus, the BART Guidelines clearly contemplate the assessment of
emission reductions.
Emission reductions are a consideration in calculating both average
and incremental cost effectiveness in order to evaluate the cost of
compliance (one of the five factors). 70 FR 39167 and 39168. Contrary
to the commenters' assertions, however, our disapproval of Wyoming's
DEQ's BART analyses is not ``based'' on emission reductions, rather the
analyses was based on the best system of continuous emission control
technology and associated emission reductions achievable, as used in
developing the BART factor information. For example, as discussed
elsewhere in this section and final notice, contrary to the Guidelines'
admonition that ``cost estimates should be based on the CCM, where
possible,'' the control cost calculations supplied by the utilities and
relied upon by Wyoming included costs not allowed by the CCM, such as
owner's costs and Allowance for Funds Utilized During Construction
(AFUDC). Thus, Wyoming's consideration of the ``cost of compliance''
for these units was not consistent with the Guidelines. Furthermore, as
explained elsewhere in this document, Wyoming's consideration of
visibility benefits was inconsistent with the Guidelines because the
State did not provide visibility modeling from which the visibility
improvement from individual controls could be ascertained. EPA's
analyses comports with the CAA and RHR requirements; therefore, we did
not consider factors outside the Agency's authority.
In regard to EPA's disapproval of Wyoming's BART decisions on five
units, EPA's decision was based on a careful weighing of the five
factors, including cost of compliance (average and incremental) and
visibility improvement. Just because EPA points out the emission
reductions does not mean that it has cited ``emission reductions'' as
the only basis for the regional haze FIP BART NOX decisions
for these units.
8. Presumptive Limits
Comment: EPA's regional haze FIP is improper because it requires
post-combustion NOX controls as BART, when EPA guidelines
make clear that only combustion controls for NOX are
contemplated. (See e.g. 77 FR at 33,053.) EPA's Preamble and other
guidance confirm that the combustion controls of LNBs and OFA (in some
form) are ``BART technology'' for the BART units. In the Preamble and
the RHR, EPA stated that, except for cyclone boilers, the ``types of
current combustion control technology options assumed include low
NOX burners, over-fire air, and coal reburning.'' 70 FR
39134; see also 39,144 (``For all other coal-fired units, our analysis
assumed these units will install current combustion control
technology.'') (emphasis added). In fact, in the Technical Support
Document used to develop the presumptive BART NOX emissions
limits, EPA explained that the ``methodology EPA used in applying
current combustion control technology to BART-eligible EGUs'' included
applying ``a complete set of combustion controls. A complete set of
combustion controls for most units includes a low NOX burner
and over-fire air.'' (``Technical Support Document, Methodology for
Developing NOX Presumptive Limits,'' EPA Clean Air Markets
Division, pg. 1 (dated June 15, 2005)).
EPA's Preamble and Appendix Y identify post-combustion controls for
NOX, such as SCR and SNCR, as ``BART technology'' for only
``cyclone'' units. EPA made it clear that for ``other units, we are not
establishing presumptive limits based on the installation of SCR.'' 70
FR 39136. Therefore, EPA's presumptive ``BART technology'' is LNBs and
some type of OFA. EPA further elaborated in the Preamble on SCR costs,
stating that although ``States may in specific cases find that the use
of SCR is appropriate, we have not determined that SCR is generally
cost-effective for BART across unit types.'' Id.; see also 40 CFR Part
51, Appendix Y, Section IV.E.5.\67\ Because EPA improperly requires
post-combustion controls in its regional haze FIP, EPA should withdraw
this requirement and approve the Wyoming SIP. If EPA desires to impose
post-combustion controls as BART NOX, it must first amend
Appendix Y through a proper rulemaking procedure.
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\67\ Commenters also suggest that, EPA has methodically changed
or selectively ignored the requirements from those which were
established in 40 CFR Part 51 and Appendix Y, which were published
in 2005. The states' SIPs, written shortly after that period, were
based on the rules and guidance provided at that time. Since then,
however, EPA has arbitrarily and continually changed its
interpretation of the regional haze regulations in order to achieve
emission reductions and other objectives well beyond those allowed
by the regional haze program. Here are a few examples of how EPA's
position has changed over the past few years with respect to the
guidance given for determining NOX BART controls.
Appendix Y provides a presumptive BART NOX rate
differentiated by boiler design and type of coal burned. EPA now
requires post-combustion controls significantly more aggressive than
the presumptive rates prescribed in Appendix Y. Appendix Y makes
distinctions for unit size, with more aggressive controls targeted
at the largest units. In Wyoming, EPA now proposes to require SCR on
units as small as 160 megawatts. The preamble to the regional haze
rules suggests that 75 percent of the electric generating units
would have BART NOX controls cost between $100 and $1,000
per ton. EPA is now imposing costs, based on its own calculations,
of $3,700 to $6,000 per ton on 100 percent of PacifiCorp's Wyoming
BART-eligible units.
SCR controls were only expected to be cost-effective controls
for cyclone units with high NOX emission rates. EPA is
now proposing post-combustion NOX controls on every BART-
eligible unit in Wyoming, including the installation of eleven SCRs.
EPA must stop changing its interpretations of the regional haze
rules and guidelines that were formalized in 2005 and move ahead
with approving the Wyoming BART analysis and the regional haze SIP
which complies with those rules and guidelines.
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Commenters further assert that, when EPA issued the RHR, it
established presumptive NOX BART limits for power plants
based on EPA's conclusions about the cost effectiveness of certain
emissions control technologies, including SCR and combustion controls.
70 FR at 39131, 39134-39136. These limits are based on EPA's
acknowledgment that NOX controls vary considerably and only
in ``relatively rare cases'' would SCR be appropriate. 69 FR 25184,
25202 (May 5, 2004). EPA's own pronouncement on the cost effectiveness
of SCR belie its finding that SCR is cost effective at Laramie River
Station.
The presumptive limits for NOX are differentiated by
boiler design and type of coal because NOX control
technologies are not ``one size fits all'' and cost effectiveness is
variable. Id. at 39134. As EPA noted in proposing presumptive
NOX BART limits, ``the removal efficiencies and costs
associated'' with NOX controls ``vary considerably,
depending upon the design and operating parameters of the particular
boiler being analyzed.'' 69 FR at 25202. For that reason, EPA proposed
(and ultimately finalized) presumptive NOX BART limits that
would not require post-combustion controls: ``States should require the
lowest emission rate that can be achieved without the installation of
post-combustion controls'' because they are ``applicable to most EGUs,
are relatively inexpensive, and are already widely
[[Page 5096]]
applied.'' Id. Indeed, EPA ``recognize[d] that a small number of the
largest power plants may need to install an SCR unit to meet this
control level. In such relatively rare cases, a State, at its
discretion, may find SCR to be appropriate if the source causes
visibility impacts sufficiently large to warrant the additional capital
cost.'' Id. (emphasis added).
EPA's presumptive BART determinations for coal-fired EGUs of
various boiler configurations demonstrate that emissions control
devices with an average cost effectiveness greater than $1,350 per ton
are not cost effective. Sargent & Lundy analyzed the presumptive BART
limits in EPA's ``Technical Support Document for BART NOX
Limits for Electric Generating Units Excel Spreadsheet'' and EPA's
``Technical Support Document--Methodology for Developing BART
NOX Presumptive Limits,'' and compiled EPA's cost
effectiveness thresholds for each boiler design and coal type. Sargent
& Lundy, ``BART Cost Effectiveness Thresholds'' (Jan. 6, 2010). Exhibit
17 to commenter 0148. The report was prepared to supplement North
Dakota's BART determination for Basin Electric's Leland Olds Station
Units 1 and 2, but is equally applicable to any BART determination for
coal-fired utility boilers, including Laramie River Station. Sargent &
Lundy concludes that based on EPA's own assumptions about acceptable
cost effective levels, ``a threshold of $1,350/ton should be used to
establish the cost-effectiveness of NOX retrofit control
technologies.'' Id. at 12.
Sargent & Lundy's report demonstrates that EPA consistently found
control technologies to be cost effective if the cost of NOX
removal was less than $1,350/ton, and not to be cost effective if the
cost of NOX removal was greater than $1,350/ton. Id. at
Figure 3 and accompanying text. For example, for all boiler categories
other than cyclone units, SCR had an overall average cost effectiveness
of $1,749/ton NOX removed and was considered not to be cost
effective. Id. at 11. Combustion controls at non-cyclone boilers had an
overall average cost effectiveness of $535/ton NOX removed
and were found to be cost effective. Id.
SCR is not cost effective at Laramie River Station because it
greatly exceeds the $1,350/ton threshold used by EPA in its presumptive
BART determinations. EPA's own flawed cost effectiveness analysis
estimates that installation of SCR at Laramie River Station would range
from between $3,589 and $3,903 per ton of NOX removed--far
above the $1,350/ton threshold used in its presumptive BART
determination. 78 FR at 34775-34776. EPA does not mention its
presumptive BART limits in its proposed disapproval of Wyoming's BART
determinations, and offers no explanation for departing from the
presumptive levels and the associated use of combustion controls. 78 FR
at 34772-34777. Moreover, when Sargent & Lundy estimated costs of SCR
at Laramie River Station based on a detailed scoping-level study, it
found that costs per ton of NOX removed would range from
$8,531 to $9,048, an amount seven times greater than the threshold used
in the presumptive BART determination. Sargent & Lundy Evaluation,
Table 7. See also Section XVIII.A.
We received numerous comments earlier that EPA's regional haze FIP
is improper because the BART units are meeting the presumptive limits
in the BART guidelines based on the installation of combustion
controls. Commenters go on to assert that the BART Guidelines only
require the installation of LNBs/OFA and that EPA determined in the
guidelines that SCR was generally not cost-effective for BART. One
commenter noted that EPA has completely ignored the presumptive BART
limits in the proposed action and that this is contrary to the express
requirements in both the RHR and the BART Guidelines. The commenter
goes on to say that EPA's attempt to completely ignore the BART limits
makes the presumptive BART limits meaningless and this is contrary to
the requirements of the CAA and the clear intent of the BART
Guidelines. One commenter asserted that the BART Guidelines show that
an alternative analysis is required only when a source cannot meet the
presumptive limits, and that while a state may choose to establish a
limit that is more stringent than the BART limit, there is nothing in
the BART Guidelines that would require a state to do so.
Commenters asserted that EPA adopted the presumptive BART limits to
establish the specific control levels required for EGUs. Commenters
point out that EPA has not repealed the presumptive limits from the
promulgated BART Guidelines, but in this action EPA does not even deign
to acknowledge the existence of the presumptive limits, as if the
presumptive BART limits were no longer a binding regulation. Commenters
argued that unless and until EPA goes through notice and comment
rulemaking to remove the presumptive emissions limits and establish
other requirements consistent with the CAA, then EPA must approve a
state's BART determination that meets the presumptive regulatory
limits.
Response: We disagree with the commenters. The CAA states the
following regarding emission limits for fossil-fuel fired generating
power plants having a total generating capacity in excess of 750 MW:
In the case of a fossil-fuel fired generating power plant having
a total generating capacity in excess of 750 megawatts, the
emissions limitations required under this paragraph shall be
determined pursuant to guidelines, promulgated by the Administrator
under paragraph (1).
EPA disagrees that the CAA mandates specific control levels (i.e.,
presumptive emission limits) for power plants with a total generating
capacity of 750 MW or greater. Rather, the CAA directed EPA to develop
guidelines for states to establish BART emission limits, and required
that power plants having a total generating capacity in excess of 750
MW follow the guidelines when establishing BART emission limits. In
response, in 2005 EPA promulgated the BART Guidelines, which provide a
detailed description of how a state must approach the BART
determination process for certain large EGUs, and required that the
determination of fossil-fuel fired power plants having a total
generating capacity greater than 750 MW must be made pursuant to the
BART Guidelines. As such, the plain reading of the CAA language makes
it clear the intent was to make the BART Guidelines mandatory for EGUs
larger than 750 MW, as opposed to presumptive limits.
Compliance with EPA's ``presumptive'' NOX emission
limits does not excuse a state from performing such an analysis,
because the presumptive limits serve as a floor, not a ceiling, for
BART. Furthermore, the presumptive limits in the Guidelines do not
supplant the Act's mandate to consider the five statutory factors, as
codified in the RHR.\68\ Additionally, commenters provide no showing
that the assumptions underlying EPA's older, generic calculations
representative of hundreds of plants in fact represent BART, under
current circumstances, at these particular plants. Moreover, far from
rendering the
[[Page 5097]]
presumptive limits ``meaningless,'' EPA's interpretation is in fact
necessary to effectuate the purpose of the Haze Rule. The fundamental
purpose of the BART requirement is to determine the ``best system of
continuous emission control technology available and associated
emission reductions achievable for each BART-eligible source.'' 40 CFR
51.308(e)(1)(ii)(A) (emphasis added). To allow states to adopt the
presumptive limits without any assessment of whether those limits
represent the ``best'' control for a particular EGU at the time of the
determination would be unreasonable in light of the overarching purpose
of the Haze Rule and the CAA's visibility requirements. The presumptive
limits ensure that states aim to achieve, at a minimum, the level of
emissions reduction that was available and cost-effective at the time
the BART Guidelines were adopted. EPA elaborated in the BART Guidelines
themselves, clarifying that the Agency expected states to not only
meet, but in appropriate cases exceed the presumptive limits: ``While
these [presumptive] levels may represent current control capabilities,
we expect that scrubber technology will continue to improve and control
costs continue to decline. You should be sure to consider the level of
control that is currently best achievable at the time that you are
conducting your BART analysis.'' 40 CFR part 51, App. Y, at IV.E.4
(emphasis added). Therefore, EPA's proposed rulemaking on the Wyoming
regional haze SIP is not contrary to the requirements of the CAA and
regulations.
---------------------------------------------------------------------------
\68\ Given the statutory mandate, a state may only avoid full
consideration of the five statutory factors if an initial
consideration demonstrates that further analysis is moot--for
example, where the state demonstrates that the subject unit already
employs the ``most stringent control available.'' 70 FR at 39165.
Where these unique circumstances are not present, a state's failure
to consider the five factors (for large EGUs, by complying with the
BART Guidelines' five-step analysis) is grounds for disapproval. CAA
Section 110(k)(3), (l); see Oklahoma, 723 F.3d at 1207-08.
---------------------------------------------------------------------------
Additionally, for each source subject to BART, the RHR, at 40 CFR
51.308(e)(1)(ii)(A), requires that states identify the level of control
representing BART after considering the factors set out in CAA section
169A(g), as follows: ``[s]tates must identify the best system of
continuous emission control technology for each source subject to BART
taking into account the technology available, the costs of compliance,
the energy and non-air quality environmental impacts of compliance, any
pollution control equipment in use at the source, the remaining useful
life of the source, and the degree of visibility improvement that may
be expected from available control technology.'' 70 FR 39158. In other
words, the presumptive limits do not obviate the need to identify the
best system of continuous emission control technology on a case-by-case
basis considering the five factors. A state may not simply ``stop'' its
evaluation of potential control levels at the presumptive level of
control if more stringent control technologies or limits are
technically feasible. We do not read the BART guidelines in appendix Y
to contradict the requirement in our regulations to determine ``the
degree of reduction achievable through the application of the best
system of continuous emission reduction'' ``on a case-by-case basis,''
considering the five factors. 40 CFR 51.301 (definition of Best
Available Retrofit Technology); 40 CFR 51.308(e).
Also, our interpretation is supported by the following language in
our BART guidelines: ``While these levels may represent current control
capabilities, we expect that scrubber technology will continue to
improve and control costs continue to decline. You should be sure to
consider the level of control that is currently best achievable at the
time that you are conducting your BART analysis.'' 70 FR 39171.
The presumptive limits are meaningful as indicating a level of
control that EPA generally considered achievable and cost effective at
the time it adopted the BART guidelines in 2005, but not a value that a
state could adopt without conducting a five factor analysis considering
more stringent, technically feasible levels of control.
Commenters focus on narrow passages of the BART guidelines to
support their view that the presumptive limits represent the most
stringent BART controls that EPA can require for regional haze.
However, these passages must be reconciled with the language of the RHR
cited above, as well as other passages of the BART guidelines and
associated preamble. A central concept expressed in the guidelines is
that a state is not required to consider the five factors if it has
selected the most stringent level of control; otherwise, a state must
fully consider the five factors in determining BART. 40 CFR part 51,
appendix Y, section IV.D.1, step 1.9.
Undoubtedly, as the commenters note, the presumptive limits for
NOX represent cost effective controls, but it is well-
understood that limits based on combustion controls do not represent
the most stringent level of control for NOX. Thus, a state
which selects combustion controls and the associated presumptive limit
for NOX as BART may only do so after rejecting more
stringent control technologies based on full consideration of the five
factors. Our interpretation reasonably reconciles the various
provisions of our regulations. We have clearly communicated our views
on this subject in other states, and, following our interpretation,
Wyoming conducted an analysis of control technologies that would
achieve a more stringent limit than combustion controls.
In promulgating a FIP for the Wyoming BART sources, we arrived at
an emission limit based on consideration of the five factors. Contrary
to the commenter's suggestion, EPA's BART guidelines do not establish a
presumptive cost effectiveness level that is a ``safe harbor'' or
``shield'' for state BART determinations, or that EPA, when
promulgating a FIP, may not exceed in determining BART. Once a FIP is
required, we stand in the state's shoes. This is not EPA establishing a
new presumptive limit or national rule; it is EPA, acting in the
State's shoes, conducting a reasonable source-specific consideration of
cost and the other regulatory factors.
9. Compliance With 40 CFR 51.308
Comment: EPA should have judged Wyoming's BART determinations on
the basis of whether or not the Wyoming BART determinations are
``necessary'' to make ``reasonable progress.'' EPA's RHRs provide two
regulatory paths to address regional haze. (See 77 FR 30953, 30957 (May
24, 2012).) ``One is 40 CFR 51.308, requiring states to perform
individual point source BART determinations and evaluate the need for
other control strategies.'' Id. ``The other method for addressing
regional haze is through 40 CFR 51.309, and is an option for nine
states termed the `Transport Region States' which include: . . .
Wyoming, . . . By meeting the requirements under 40 CFR 51.309, states
are making reasonable progress toward the national goal of achieving
natural visibility conditions for the 16 Class I areas on the Colorado
Plateau.'' Id. Wyoming submitted the Wyoming regional haze SIPs under
Section 309. Therefore, the requirements of Section 308 only apply to
the extent required by Section 309. Importantly, NOX
emissions and controls under Section 309 are treated differently than
NOX emissions and controls under Section 308. This is
because Congress and EPA purposefully focused Section 309 on addressing
the issue of SO2 emissions, the predominant cause of
regional haze on the Colorado Plateau in the western US. By contrast,
Section 309 recognizes that NOX emissions have a
significantly smaller impact on visibility on the Colorado Plateau. In
fact, the WRAP report estimated that ``stationary source NOX
emissions result in nitrates that probably cause about 2 to 5 percent
of the impairment on the Colorado Plateau.'' Several illustrations in
the WRAP NOX report show that nitrate emissions have very
little impact on Class I areas in or near Utah and
[[Page 5098]]
Wyoming. The WRAP report also explains that ``NOX controls
will have a relatively small impact on PM and visibility in the West.''
The Wyoming SIP, including BART determinations for NOX,
is consistent with the WRAP's NOX information, and also
properly acknowledges the relatively small impact nitrates from
stationary sources like PacifiCorp's BART units have on visibility
impairment in Wyoming. Wyoming's SIP, page 62, states that ``the
majority of nitrate stems from mobile sources.'' The SIP also explains
that in all but one Class I area ``contributions from other states and
Canada are much larger than contributions from inside Wyoming.'' Id.
Wyoming correctly determined, consistent with the WRAP reports and
other data, that controlling NOX emissions from stationary
sources like PacifiCorp's BART units would yield very little visibility
improvement in Wyoming. EPA's own regional haze visibility map shows
that visibility in Wyoming is among the best in the country.
In light of the above information, it is understandable that
Section 309 focuses on addressing SO2 emissions. Indeed,
WRAP focused their efforts primarily on SO2 emissions
because the research indicated this pollutant had the greatest impact
on visibility. ``Recommendations for Improving Western Vistas,''
authored by the Grand Canyon Visibility Transport Commission, (June 10,
1996) at page 32 (identifying sulfates as ``the most significant
contributor to visibility impairment'' from stationary sources). In a
separate action, EPA acknowledged that Wyoming has complied with the
Section 309's SO2 requirements and made great progress
towards improving and protecting visibility as a result. For all of
these reasons, Section 309 takes a different approach to NOX
emissions than does Section 308, placing much less emphasis on the need
for significant reductions in NOX emissions and instead
focusing almost all attention and resources in the western U.S. on
reducing SO2 emissions. EPA's FIP, with its incredibly
expensive and unneeded NOX control equipment, ignored the
focus and intent of Section 309 and refused to acknowledge the
discretion available to Wyoming to balance this information in making
its BART determinations.
Additionally, as a result of the lesser emphasis in Section 309 on
NOX emissions, Section 51.309(d)(4)(vii) requires a regional
haze SIP to ``contain any necessary long term strategies and BART
requirements for stationary source . . . NOX emissions.''
Section 308, by contrast, does not include a similar ``necessary to
achieve reasonable progress'' threshold for BART. The difference
between the two requirements is both intentional and meaningful. If a
state like Wyoming finds that a particular BART requirement is not
``necessary'' to make ``reasonable progress,'' then that BART
requirement should not be required as part of the regional haze SIP.
This interpretation is supported by EPA's own position in Central
Arizona Water Conservancy District v. United States, 990 F.2d 1531 (9th
Cir. 1993). There, ``EPA chose not to adopt the emission control limits
indicated by the BART analysis, but instead to adopt an emissions
limitations standard that would produce greater visibility improvement
at a lower cost.'' Id. at 1543. The court agreed with EPA, stating that
``Congress's use of the term `including' in Section 7491(b)(2) prior to
its listing BART as a method of attaining `reasonable progress'
supports EPA's position that it has the discretion to adopt
implementation plan provisions other than those provided by BART
analyses in situations where the agency reasonably concludes that more
`reasonable progress' will thereby be attained.'' Id. This same
rationale applies to the term ``necessary'' in Section 309. Therefore,
in rejecting Wyoming's regional haze SIP and adopting a FIP, EPA is
required to show that the Wyoming SIP will not achieve ``necessary
reasonable progress'' towards the visibility goal, and EPA's FIP will.
EPA has failed to provide any support for such a position.
Other comments suggest that by meeting the requirements under 40
CFR 51.309, states are making reasonable progress toward the national
goal of achieving natural visibility conditions for the 16 Class I
areas on the Colorado Plateau. Wyoming submitted its regional haze SIPs
under section 51.309. Therefore, the requirements of section 51.308
only apply to the extent required by section 51.309.
Wyoming's regional haze SIP is consistent with WRAP's
NOX information, and also emphasizes the relatively small
impact nitrates that stationary sources have on visibility issues in
Wyoming. Wyoming correctly determined, consistent with the WRAP reports
and other data, that controlling NOX emissions from
stationary sources like PacifiCorp's units would yield very little
visibility improvement in Wyoming. Section 51.309 understandably is
intended to focus on SO2 due to the greater visibility
impact from SO2. In a separate action, EPA acknowledged that
Wyoming has complied with the section 51.309's SO2
requirements and made great progress towards improving and protecting
visibility as a result.
As a result of the lesser emphasis in section 51.309 on
NOX emissions, 40 CFR 51.309(d)(4)(vii) requires a regional
haze SIP to ``contain any necessary long term strategies and BART
requirements for stationary source . . . NOX emissions.''
Section 51.308, by contrast, does not contain a similar ``necessary''
threshold for BART. If a BART requirement is not ``necessary'' for a
section 51.309 state, such as Wyoming, to make ``reasonable progress,''
then it is not required as part of the regional haze SIP. In other
words, section 51.309 allows a state even more discretion because of
this ``necessary'' requirement than would otherwise be allowed under
section 51.308. Wyoming has authority to adopt those regional haze SIP
provisions that it believes provide for ``reasonable progress,'' even
when those plan provisions do not align directly with BART as that may
be determined under Section 51.308.
40 CFR 51.309(d)(4)(vii) provides that ``[a]ny such BART provisions
may be submitted pursuant to either 51.308(e)(1) or 51.308(e)(2).'' By
using the permissive term ``may,'' EPA makes clear that such a
submission, under either subsection, is voluntary and not mandatory for
section 51.309 states. For this reason, Wyoming, as a WRAP state, was
never required to comply with 40 CFR 51.308(e)(1)(ii)(A) and is only
required to include whatever BART NOX determinations are
``necessary,'' as determined by the State. If Wyoming's section
51.309's SO2 controls already provide the adequate level of
visibility improvement and protection, then, by definition, little or
no BART NOX controls would be ``necessary.'' EPA has failed
to show how any ``necessary'' NOX controls were excluded
from the Wyoming regional haze SIP; therefore it should approve
Wyoming's regional haze SIP.
Response: We disagree with these comments. As explained in our
proposed rulemaking for section 51.309(d)(4)(viii), we explained that
the provision ``is intended to clarify that if EPA determines that the
SO2 emission reductions milestones and backstop trading
program submitted in the section 51.309 SIP makes greater reasonable
progress than BART for SO2, this will not constitute a
determination that BART for PM or NOX is satisfied for any
sources which would otherwise be subject to BART for those pollutants''
(emphasis added). 70 FR 44169 (Aug. 1, 2005). EPA does not interpret
this rule to mean that there are different BART requirements for
section 308 and 309
[[Page 5099]]
regional haze SIPs. EPA's rulemaking made no finding that BART
determinations conducted for a state submitting a SIP under section
51.309 should be conducted any differently than a state submitting a
FIP under only section 308. The use of the word ``necessary'' in
section 51.309(d)(4)(viii) was to explain that some states may have
BART NOX emission limitations, while others may not. As
already explained elsewhere in proposal and our response to other
comments, Wyoming did not conduct a proper evaluation of the five
statutory factors, as required by 40 CFR 51.308(e)(1)(ii)(A) and
section 169A(g) of the CAA.
EPA also disagrees with commenter's assertion that a BART
submission is discretionary. 40 CFR 51.309(d)(4)(viii) is clear in that
the implementation plan ``must'' contain BART requirements. The
proposed rulemaking explained that the provision that provides that
``[a]ny such BART provisions may be submitted pursuant to either
Section 51.308(e)(1) or 51.308(e)(2),'' was included to ``allow States
the flexibility to address these BART provisions either on a source-by-
source basis under Section 51.308(e)(1), or through an alternative
strategy under Section 51.308(e)(2).'' 70 FR 44169 (Aug. 1, 2005).
Moreover, EPA's proposal made clear that ``[i]n limited
circumstances, it may be possible for a State to demonstrate that an
alternative program which controls only emissions from SO2
could achieve greater visibility improvement than application of
source-specific BART controls on emissions of SO2,
NOX and/or PM. We nevertheless believe that such a showing
will be quite difficult to make in most geographic areas, given that
controls on SO2 emissions alone in most cases will result in
increased formation of ammonium nitrate particles.'' 70 FR 44169 (Aug.
1, 2005). Wyoming's RH SIP does not include a demonstration that the
backstop SO2 trading program under Section 51.309 achieves
greater visibility improvement than application of source-specific PM
BART controls. Therefore, Wyoming's Section 51.309 SIP does not provide
the adequate level of visibility improvement to meet the BART
requirements.
With respect to the relationship of BART and requirements for
reasonable progress under 40 CFR 51.308, EPA interprets the reasonable
progress requirements to apply to BART sources. As explained in our
guidance, due to the similarity of the BART and reasonable progress
factors, states may reasonably rely on their BART determinations to
show reasonable progress for those sources for the first planning
period. However, BART is an independent requirement of the statute and
the RHR. We have disapproved certain BART determinations by Wyoming not
due to a failure to make reasonable progress, but due to a failure to
consider the BART factors appropriately.
10. Legal Analysis
Comment: We received comments that the proposed rule is costly and
that preliminary calculations by the State of Wyoming showed that the
BART and long-term strategies under the proposed rule will cost over
$170 million on an annualized basis; with total capital cost will be
over $1 billion, and annual operating costs of nearly $600 million.
Commenters went on to say that since the rulemaking action will exceed
$100 million dollars in annual costs it should be reviewed according to
the standards established in Executive Orders 12866 and 13563. * * *
Another commenter notes that EPA has also failed to conduct any
analysis of the impacts under the Unfunded Mandates Reform Act (UMRA).
In addition to the capital costs of nearly $750,000,000 for Laramie
River Station alone, the annual operating costs of an SCR system at
Laramie River Station are over $ 15,000,000. The commenter asserts that
this amount is nearly double that projected by EPAs expert Andover of
just under ($5,000,000), using generalized information. These annual
operating costs, on top of the capital costs, for the three units at
Laramie River Station alone, are significant, and when coupled with the
impacts for the remaining five PacifiCorp units, far exceed the
thresholds of the UMRA.
The UMRA is designed to ensure that Congress and federal agencies
analyze the impact of proposed statutes and regulations on local
governments and other entities before taking action. Where the
estimates indicate at least a $50 million per fiscal year direct cost
of all intergovernmental mandates, or a $100 million per fiscal year
direct cost of private sector mandates, an analysis is required to
evaluate the impact on local governments and private entities, and if
necessary, the mandate must be funded. Western Minnesota, Missouri
River Energy Services, and the governmental entities they serve--
together with the others served by the remaining co-owners of Laramie
River Station--will feel an annual impact in excess of $50 million per
year should the EPA's FIP become final. Failure of EPA to conduct any
analysis of the impact of imposing an unfunded mandate on the small
governmental entities served by Laramie River Station, and the other
BART units in Wyoming shows a blatant disregard for the regulatory
process and protections that are to be accorded such significant
rulemakings.
Earlier comments argued that the UMRA has been applied to EPA
actions where the costs to regulated entities in numerous states have
been aggregated. Based upon this precedent, PacifiCorp believes that
EPA should aggregate all regional haze compliance costs across Wyoming,
Utah, Colorado and Arizona for PacifiCorp, which would easily exceed
the $100 million threshold. At a minimum, EPA should aggregate costs
for EPA's FIPs in Wyoming and Arizona, which would also exceed the $100
million threshold.
Additional earlier comments suggested that the UMRA requires
federal agencies to identify unfunded federal mandates. For rules that
contain federal mandates, such as EPA's regional haze FIP action
requiring expensive pollution controls, title II of UMRA requires the
agencies to prepare written statements, or ``regulatory impact
statements,'' (RIS) containing specific descriptions and estimates,
including a qualitative and quantitative assessment of the anticipated
costs and benefits of the mandate. This requirement is triggered by any
rule that ``may result in the expenditure by state, local, and tribal
governments, in the aggregate, or by the private sector, of
$100,000,000 or more (adjusted annually for inflation) in any 1 year. .
.'' 2 U.S.C. 1532(a).
When a RIS is required, the agency is also required to ``identify
and consider a reasonable number of regulatory alternatives and from
those alternatives select the least costly, most cost effective, or
least burdensome alternative that achieves the objectives of the rule''
or explain why that alternative was not selected. 2 USCA Section 1535.
Here, EPA has failed to comply with the UMRA, arguing that the
regional haze FIP ``does not contain a federal mandate that may result
in expenditures that exceed the inflation adjusted UMRA threshold of
$100 million.'' EPA is wrong. PacifiCorp currently anticipates spending
more than $100 million dollars in at least 2014 ($104 million), 2015
($175 million), and 2016 ($154 million) to comply with EPA's regional
haze FIP for Wyoming (based on alternative ``one'' for the Jim Bridger
plant). If the regional haze compliance costs imposed by EPA's proposed
FIP in Arizona and EPA's approval of the Colorado regional haze SIP are
factored in, the costs to PacifiCorp in a given
[[Page 5100]]
year would be significantly higher. Also, when the BART NOX
and PM determinations are approved by EPA for Utah, these costs to
PacifiCorp in a given year could be much, much higher.
Response: We disagree with this comment. Under section 202 of the
UMRA, before promulgating any final rule for which a general notice of
proposed rulemaking was published, EPA must prepare a written
statement, including a cost-benefit analysis, if that rule includes any
``Federal mandates'' that may result in expenditures to State, local,
and Tribal governments, in the aggregate, or to the private sector, of
$100 million or more (adjusted for inflation) in any one year. EPA has
determined that this rule does not contain a Federal mandate that may
result in expenditures that exceed the inflation-adjusted UMRA
threshold of $100 million (in 1996 dollars) by State, local, or Tribal
governments or the private sector in any one year. We estimate that the
total annual costs in the aggregate are approximately $93 million (see
Table 1).
Comment: EPA's regional haze FIP states that EPA's proposed action
is not subject to Executive Order 13211, ``Actions Concerning
Regulations that Significantly Affect Energy Supply, Distribution, or
Use'' (66 FR 28,355 (May 22, 2001)), because the proposed action ``is
not a significant regulatory action under Executive Order 12866.'' 78
FR 34790. EPA further claims the proposed regional haze FIP is not a
``significant regulatory action'' under Executive Order 12866 because
the ``proposed FIP applies to only five facilities'' and is ``therefore
not a rule of general applicability.'' EPA is incorrect, and should
withdraw its regional haze FIP.
Executive Order 13211 provides that agencies shall submit a
statement of energy effects for matters ``identified as significant
energy actions.'' A ``significant energy action'' is defined as ``any
action by an agency . . . that promulgates or is expected to lead to
the promulgation of a final rule or regulation . . . that is a
significant regulatory action under Executive Order 12866 or any
successor order'' and ``likely to have a significant adverse effect on
the supply, distribution, or use of energy''; or is ``designated by the
Administrator of the Office of Information and regulatory Affairs as a
significant energy action.'' Id. Section 4(b) (emphasis added).
Executive Order 12866, in turn, which concerns Regulatory Planning and
Review, defines a ``significant regulatory action'' as any regulatory
action that is likely to result in a rule that may: (1) Have an annual
effect on the economy of $100 million or more or adversely affect in a
material way the economy, a sector of the economy, productivity,
competition, jobs, the environment, public health or safety, or State,
local, or tribal governments or communities. 58 FR 51735, 51738 (Oct.
4, 1993)
According to PacifiCorp's current estimates (excluding allowance
for funds used during construction (AFUDC)), it will spend more than
$100 million dollars in capital costs alone in 2014 ($225 million),
2015 ($139 million), 2017 ($146 million) and 2018 ($118 million) to
comply with EPA's regional haze FIP for Wyoming (based on alternative
``one'' for the Jim Bridger plant). If regional haze compliance costs
currently imposed or approved by EPA on PacifiCorp's BART Units in
Arizona and Colorado are factored in, the total capital cost impacts to
PacifiCorp in any given year would be significantly higher; increasing
to approximately $246 million in 2014, $190 million in 2015, $168
million in 2016, $181 million in 2017, and $118 million in 2018. Also,
because the BART NOX and PM determinations have not yet been
approved by EPA for PacifiCorp's BART Units in Utah, EPA's ultimate
BART requirements in Utah likely will add even more costs in
overlapping installation and compliance years, with total project costs
for SCR installations on PacifiCorp's Utah units currently estimated to
cost in excess of $150 million per unit to install (again, excluding
AFUDC). Based upon these basic costs alone, there is no doubt that
EPA's FIP meets the definition of a ``significant regulatory action.''
Other large costs, including those related to EPA's BART determinations
for Basin Electric, also should be factored into this analysis together
with PacifiCorp's costs because they are part of the same ``sector of
the economy.'' Also, as demonstrated by PacifiCorp's July 12, 2012,
submittal in this docket, EPA's regional haze FIP will have an adverse
effect on the supply and distribution of electricity within
PacifiCorp's system. Therefore, EPA's determination that Executive
Order 13211 did not apply is incorrect, and arbitrary and capricious.
Moreover, EPA has admitted in the proposed rule that system-wide
``affordability'' costs should be part of the BART analysis. 78 FR
34756. Because EPA's FIP is a ``significant regulatory action,'' EPA
must prepare a ``Statement of Energy Effects'' for the Administrator of
the Office of Information and Regulatory Affairs, Office of Management
and Budget. (See Executive Order 13211, Section 2.) Because EPA did not
do so, the regional haze FIP is improper.
Executive Order 12866, in turn, which concerns Regulatory Planning
and Review, defines a ``significant regulatory action'' as any
regulatory action that is likely to result in a rule that may: (1) Have
an annual effect on the economy of $100 million or more or adversely
affect in a material way the economy, a sector of the economy,
productivity, competition, jobs, the environment, public health or
safety, or State, local, or tribal governments or communities.''
Also, as demonstrated by PacifiCorp's July 12, 2012 submittal in
this docket, EPA's regional haze FIP action will have an adverse effect
on the supply and distribution of electricity within PacifiCorp's
system. Therefore, EPA's determination that Executive Order 13211 did
not apply is incorrect, and arbitrary and capricious.
Moreover, because EPA's regional haze FIP action is a ``significant
regulatory action,'' before imposing its regional haze FIP EPA must
first prepare a ``Statement of Energy Effects'' for the Administrator
of the Office of Information and Regulatory Affairs, Office of
Management and Budget. Such a statement must include a ``detailed
statement'' by the agency concerning ``any adverse effects on energy
supply, distribution, or use (including a shortfall in supply, price
increases . . .) should the proposal be implemented,'' and ``reasonable
alternatives to the action with adverse energy effects and the expected
effects of such alternatives on energy supply, distribution, and use.''
Accordingly, based on an analysis of the relevant factors, EPA's
regional haze FIP is improper because EPA failed to conduct the
required regulatory analysis and failed to prepare the required
documentation.
Executive Order 12866, in turn, which concerns Regulatory Planning
and Review, defines a ``significant regulatory action'' as any
regulatory action that is likely to result in a rule that may: (1) Have
an annual effect on the economy of $100 million or more or adversely
affect in a material way the economy, a sector of the economy,
productivity, competition, jobs, the environment, public health or
safety, or State, local, or tribal governments or communities.''
Response: EPA disagrees that Executive Order 13211 applies to this
action. Order 13211 is only applicable to an agency regulation that is
a ``significant regulatory action'' under Executive Order 12866.
Executive Order 13211(4)(b). Order 13211 also explicitly adopts the
definitions of ``regulation'' and ``rule'' as explained in Executive
Order 12866. Executive Order
[[Page 5101]]
13211(4)(a). However, this action does not fit within the definition of
Executive Order 12866, which defines a ``regulation'' or ``rule'' as an
``agency statement of general applicability.'' Executive Order
12866(3)(d). Here, EPA's action was individually tailored for a limited
number of BART eligible sources in Wyoming and is not generally
applicable. Thus this action is not governed by Order 12866 and,
therefore, is also not governed by Executive Order 13211. As discussed
in more detail in Statutory and Executive Orders Review section of this
document, the costs for this action are about $93 million annually.
Moreover, as explained in more detail elsewhere, EPA took the cost
of compliance into consideration when making BART determinations to
ensure this rule's requirements are beneficial and not unduly
burdensome. The commenter is correct that EPA may, in its discretion,
consider system affordability costs beyond the direct compliance costs
on an individual facility in extraordinary circumstances. As explained
in the Basis for Final Action section and elsewhere in the proposed and
final actions, we proposed to approve the State's BART and reasonable
progress determinations for Jim Bridger Units 1 and 2, but on a
different basis.\69\ In response to our proposal, we received both
supportive and adverse comments regarding whether the affordability
provisions of the BART Guidelines should apply to Units 1 and 2. As
explained in more detail in our responses to these comments, we agree
that PacifiCorp did not make a sufficient showing that it could not
afford to install LNB/SOFA + SCR on Units 1 and 2 within the five-year
compliance period. Nevertheless, we also received new information
regarding the costs of compliance and visibility benefits associated
with Jim Bridger and have revised our cost estimates and visibility
modeling for all four units accordingly. Using this revised
information, we re-evaluated the five BART factors. Ultimately however,
while we believe that these costs and visibility improvements could
potentially justify LNB/SOFA + SCR as BART, because this is a close
call and because the State has chosen to require SCR as a reasonable
progress control, we believe deference to the State is appropriate in
this instance. We are therefore finalizing our approval of the State's
determination to require SCR at Jim Bridger Units 1-4, with an emission
limit of 0.07 lb/MMBtu (30-day rolling average), as part of its LTS. We
also note that, neither the CAA nor the regional haze regulations
require EPA to consider costs beyond an individual facility's direct
compliance costs. 42 U.S.C.A. Section 7491(g)(1), (2); 40 CFR 51.301.
Further, nothing in the Order is to be construed to impair or otherwise
affect the authority granted by law to EPA, nor does it create any
right or benefit enforceable at law.\70\
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\69\ There, we indicated that given the number of SCR retrofits
PacifiCorp had to perform in Wyoming and in other states, it might
not be affordable for PacifiCorp to install two additional SCRs on
Jim Bridger Units 1 and 2 within the five-year BART compliance
period. We requested additional information from commenters
regarding whether the affordability provisions of the BART
Guidelines should be applied to Units 1 and 2. In the alternative,
we proposed to find that NOX BART for Units 1 and 2 was
an emission limit of 0.07 lb/MMBtu (30-day rolling average) based on
the installation of LNB/SOFA + SCR with a compliance deadline of
five years. Under this scenario, we acknowledged that the cost-
effectiveness of LNB/SOFA + SCR at Units 1 and 2 was within the
range of what EPA and the State itself had found reasonable in other
BART determinations. We also considered the significant visibility
improvement demonstrated by the State's modeling to warrant LNB/SOFA
+ SCR as BART.
\70\ For example, EO 12866 (Sec. 10, Judicial review) explicitly
states, ``This Executive order is intended only to improve the
internal management of the Federal Government and does not create
any right or benefit, substantive or procedural, enforceable at law
or equity by a party against the United States, its agencies or
instrumentalities, its officers or employees, or any other person.''
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Comment: The EPA's FIP fails to account for the significant
economic impacts on small entities as required by the Regulatory
Flexibility Act. The estimated capital cost alone to install SCRs at
Laramie River Station only is nearly $750,000,000. For Western
Minnesota and its members the total impact would result in an increase
in wholesale electric rates of twelve percent, which includes a ten
percent increase due to the capital costs for installation of the SCRs
and an additional increase of two percent annually for operating
expenses. The members of Western Minnesota and Missouri River Energy
Services are small governmental units, which must be given
consideration under the Regulatory Flexibility Act.
Under the Regulatory Flexibility Act, EPA is required to analyze
the economic impact of proposed regulations when there is likely to be
a significant economic impact on a substantial number of small
entities, and to consider regulatory alternatives that will achieve the
agency's goal while minimizing the burden on small entities. The
certification that EPA has provided with this proposed rule is
perfunctory at best, and does not seek to analyze the actual elements
required by the Regulatory Flexibility Act.
The EPA has wholly failed to conduct any regulatory flexibility
analysis pursuant to the Regulatory Flexibility Act, which further
demonstrates the arbitrariness of this proposed FIP. If it had, it
would acknowledge that the Wyoming SIP for NOX provides a
reasonable alternative that has a far less significant economic impact
on small entities while providing virtually the same improvement in
visibility.
Response: EPA disagrees with this comment. Courts have interpreted
the Regulator Flexibility Act to require a regulatory flexibility
analysis only when a substantial number of small entities will be
subject to the requirements of the agency's action. See, e.g., Mid-Tex
Elec. Co-op, Inc. v. FERC, 773 F.2d 327, 342 (D.C. Cir. 1985). The
economic analysis described in the Regulatory Flexibility Act is not
required; however, if the head of an agency certifies that the rule
will not have a significant economic impact on a significant number of
small entities. 5 U.S.C. 605(b). As the commenter noted, such
certification was made by EPA and published in the Federal Register as
required by the act. No other action is required by EPA because the
agency is not imposing any requirements on small entities. Here, only a
limited number of entities have incurred compliance obligations under
this action, and none of those entities are ``small entities.''
EPA still seeks to minimize the impact of its actions have on small
entities. EPA sought comments regarding the economic impact from all
entities affected by this action and carefully considered all relevant
information. As described elsewhere, EPA believes that this action is
necessary to achieve the objectives of the CAA and that the visibility
improvements justify the costs of this rule, as established in the Act
and implementing regulations.
Comment: The underlying purpose of Executive Order 12866 (Order) is
to foster a regulatory regime that respects the role of local
government, recognizes that the private sector is the ``best engine for
economic growth,'' and appreciates the need to develop regulations that
do not impose ``unacceptable or unreasonable costs on society.'' Exec.
Order No. 12,866, 58 FR 51735 (Oct. 4, 1993). The Order requires
agencies that propose a significant regulatory action to consider a
multitude of quantitative and qualitative factors during the rulemaking
process. Id.
A ``significant regulatory action'' is one in which the resulting
rule is likely to ``[h]ave an annual effect on the economy of $100
million or more or
[[Page 5102]]
adversely affect in a material way the economy, a sector of the
economy, productivity, competition, jobs . . . or State, local, or
tribal governments or communities.'' 58 FR 51735.
Allow us, by way of example, the opportunity to outline the
significance that the proposed rule will have on one of Wyoming's
counties. The Laramie River Station (Station), one of the five targeted
EGUs under the proposed FIP, is the largest employer in Platte County.
These are good paying jobs that include health and retirement benefits
for the Station's employees. In a rural county with 8,800 people, where
the average annual household income is $46,916, there is concern that
the use of a control regime as proposed in the FIP may make operation
of the Station substantially cost-prohibitive and therefore jeopardize
some of the best jobs in Platte County. Moreover, the retrofitting
outlined in the proposed rule will likely increase the electric rates
of some of Wyoming's most vulnerable citizens.
The Station also provides a significant source of revenue for
Platte County. In the 2012 Fiscal Year, the Station provided over $3.7
million in state assessed taxes. This is a significant source of
revenue for Platte County, revenue that is needed to sustain essential
government functions, such as operation of the county jail, maintaining
county roads and bridges, and county health services. Platte County is
but one example. Each of the other potentially affected counties
(Converse, Lincoln, and Campbell) share those three principal concerns:
(1) The targeted EGUs provide a significant source of employment to
county residents, (2) volatility of electric rates on some of Wyoming's
most vulnerable citizens, and (3) the EGUs provide a significant source
of revenue in order to sustain essential county services.
For these reasons, Wyoming's County Commissioners cannot accept
EPA's conclusion that the proposed rule is not a significant regulatory
action. Accordingly, because the proposed rule is a significant
regulatory action, it should be subject to review in accordance with
Executive Order 12866 and, by extension, Executive Order 13563.
Response: Executive Order 13563 is supplemental to and reaffirms
the principles, structures, and definitions governing contemporary
regulatory review that were established in Executive Order 12866 of
September 30, 1993. In general, the Order seeks to ensure the
regulatory process is based on the best available science; allows for
public participation and an open exchange of ideas; promotes
predictability and reduces uncertainty; identifies and uses the best,
most innovative, and least burdensome tools for achieving regulatory
ends; and takes into account benefits and costs, both quantitative and
qualitative. However, nothing in the Order shall be construed to impair
or otherwise affect the authority granted by law to the Agency. In our
review process the cost of compliance was one of the elements addressed
to ensure that the requirements to achieve the goals stated in the CAA
were beneficial and not burdensome to the regulated entity. Please
refer elsewhere in our response to comments (e.g., Introduction and
BART sections) for a detailed analysis of the elements required by the
CAA and RHR for BART determinations.
Comment: EPA, through this proposed rule, fails to recognize, or
even to make an effort to understand, the burden imposed upon Wyoming
and its local governmental entities. If it had done so, it would have
acknowledged the fundamental value and attainable progress derived from
Wyoming's regional haze SIP. Instead, what EPA proposes is a
disingenuous and poorly crafted rule that ignores fundamental realities
existing in the counties of Wyoming, that they are rural, traditionally
low-income, and the economic drivers are typically limited to tourism,
agriculture, or industry. As such, the proposed rule would create a
disproportionate impact on those communities playing host to industry.
``Not in my backyard'' is simply not an option for many rural
communities. It therefore poses a fundamental question of equity, a
concern reiterated in Executive Order 13563. Executive Order No.
13,563, 76 FR 3821 (Jan. 18, 2011). Concerns regarding equity require
the EPA to consider who is bearing the cost of the proposed rule. The
bottom line is that increased energy costs that will result from the
proposed FIP will disproportionately hurt our local economies.
Additional comments argue that EPA is required to seek views of
appropriate local officials' before imposing regulatory requirements
that might significantly or uniquely affect a particular governmental
entity. EPA must then seek to minimize any burdens that significantly
or uniquely affect the local governmental entity in a manner that is
consistent with achieving the underlying regulatory objective.
Response: EPA disagrees with this comment. Executive Order 13563 is
supplemental to and reaffirms the principles, structures, and
definitions governing contemporary regulatory review that were
established in Executive Order 12866. Executive Order 13563 Section
1(b). In general, the Order seeks to ensure the regulatory process is
based on the best available science; allows for public participation
and an open exchange of ideas; promotes predictability and reduces
uncertainty; identifies and uses the best, most innovative, and least
burdensome tools for achieving regulatory ends; and takes into account
benefits and costs, both quantitative and qualitative. However, nothing
in the Order shall be construed to impair or otherwise affect the
authority granted by law to EPA, nor does it create any right or
benefit enforceable at law. Executive Order 13563 Section 7(b), (d).
Each BART source was examined and the cost of compliance was one of the
factors addressed to ensure the rule's requirements are beneficial and
not unduly burdensome to the regulated entities. We also note the
following: (1) There will likely be beneficial effects on tourism due
to improved visibility at the Class I areas; \71\ (2) emission controls
can be installed over a period of time; and (3) in this final action we
are mostly approving the provisions of the State's SIP. Moreover, as
explained above, courts have interpreted the Regulatory Flexibility Act
to require a regulatory flexibility analysis only when a substantial
number of small entities will be subject to the requirements of the
agency's action. While EPA has not made a determination that a
substantial number of small entities will be subject to the
requirements of this final action, we nevertheless seek to minimize the
impact our actions have on small entities. EPA sought comments
regarding the economic impact from all
[[Page 5103]]
entities affected by this action and carefully considered all relevant
information. As described elsewhere, EPA believes that this action is
necessary to achieve the objectives of the CAA and that the visibility
improvements justify the costs of this rule, as established in the Act
and implementing regulations. Please refer elsewhere for a detailed
analysis of the elements required by our regulations for BART
determinations.
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\71\ Results of visitor surveys from 22 studies demonstrate that
clean air and scenic vistas in national parks consistently rank as
the top priorities of 90 percent or more of visitors. ``National
Park Service Visitor Values & Perceptions of Clean Air, Scenic Views
& Dark Night Skies 1988-2011,'' Natural Resource Report NPS/NRSS/
ARD/NRR-2013/632 (Feb. 2013), pp. 16-23 (including specific studies
focused on Wyoming's national parks). Additionally, as explained in
recent National Park Service (NPS) and U.S. Forest Service (USFS)
reports, the national parks and U.S. Forest Service lands are
important economic engines for local communities and businesses,
with visitors generating significant economic activity and support
thousands of jobs. See, ``Economic Benefits to Local Communities
from National Park Visitation, 2011,'' National Park Service,
Natural Resource Report NPS/NRSS/ARD/NRR-2013/632 (Feb. 2013) (NPS
2013 Report); and ``National Visitor Use Monitoring Results,
National Summary Report,'' USDA Forest Service (May 20, 2013
update). In 2011, the NPS report indicates that non-local visitor
spending to the national parks in Wyoming was $621 million, creating
more than 9,000 jobs. NPS 2013 Report, p. 26. The Grand Teton
National Park alone had more than 2.5 million visitors who spent
$463 million which created more than 6,000 jobs. NPS 2013 Report, p.
19.
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Comment: In imposing these additional costs the proposed action
will unnecessarily impact power generation in Wyoming and lead
ultimately to increased utility costs for Wyoming residents. Along
these lines, we believe the proposed action fails to comply with
Executive Order 13132. The notice of proposed action states: ``Under
Executive Order 13132, EPA may not issue a regulation that has
federalism implications, that imposes substantial direct compliance
costs, and that is not required by statute, unless the federal
government provides the funds necessary to pay the direct compliance
costs incurred by state and local governments, or EPA consults with
state and local officials early in the process of developing the
proposed regulation.'' The notice switches that standard by concluding:
``This rule will not have substantial direct effects on the states, on
the relationship between the national government and the states, or on
the distribution of power and responsibilities among the various levels
of government, as specified in Executive Order 13132, because it merely
addresses the State not fully meeting its obligation to prohibit
emissions from interfering with other states measures to protect
visibility established in the CAA. Thus, Executive Order 13132 does not
apply to this action.'' (78 FR 34790).
The conclusion that Executive Order 13132 does not apply to this
action appears inconsistent with the standard of the Order. The
regulation will impose substantial direct compliance cost on local
governments and there is no provision for funding those costs by the
federal government. The Wyoming Municipal Power Agency (WMPA) is a
joint powers board created by eight Wyoming municipalities to generate
and transmit electricity for the residents of those municipalities.
Through a partnership, WMPA and thus each of those municipalities, own
a substantial interest in the Laramie River Station. WMPA estimates
that the EPA's proposal would cost an estimated $600 million for the
Laramie River Station. When costs are imposed upon a facility, owners
of that facility must initially bear those costs. Whether the
generating facility is owned 100% by a single municipality, or shared
through a partnership or cooperative, as a result of that ownership
interest a substantial direct compliance cost is imposed on the
municipal owners.
Response: EPA disagrees that Executive Order 13132 applies to this
action. The Order only applies to agency actions that fit within the
Order's definition of ``policies that have federalism implications.''
The Order defines such actions as rules ``that have substantial direct
effects on states, on the relationship between the national government
and the States, or on the distribution of power and responsibilities
among the various levels of government.'' Executive Order 13132 Section
(1)(a). In contrast, this action merely addresses Wyoming's existing
obligations under the CAA and thus does not impose any additional
burdens beyond that which the law already requires. Because this rule
does not fit within the definition of ``policies that have federalism
implications,'' the Order does not apply to this action.
Moreover, the additional elements of the standard urged by the
commenter do not apply to this action. EPA must consult a state or
provide funding only if a regulation that has federalism implications
(1) imposes substantial direct compliance costs on state and local
governments, and (2) is not required by statute. Executive Order 13132
Section (6)(b). First, as the commenter noted, the regulation imposes
compliance costs on Laramie River Station, not directly on state or
local governments. Municipalities may possibly be indirectly impacted
because of their membership in WMPA, which in turn retains a 1.37%
ownership interest in Laramie River Station through a partnership with
the Missouri Basin Power Project. However, this action does not impose
any direct compliance costs on local governments. Second, the CAA
requires that states promulgate adequate SIPs to achieve the CAA's
visibility goals, and further requires EPA to promulgate FIPs if a
state fails to meet its obligations. 42 U.S.C. 7492(3)(2), Section
7410(c)(1); see also WildEarth Guardians v. Jackson, No. 11-CV-00001-
CMA-MEH, 2011 WL 4485964 at *6 (D. Colo. Separt 27, 2011) (finding
EPA's duty to either approve a state regional haze SIP or promulgate a
FIP is nondiscretionary). Because this action does not have federal
implications, does not impose direct compliance costs on local
governments, and is required by statute, Executive Order 13132 does not
apply to this action.
Comment: EPA did not properly vet its proposed FIP against a number
of requirements detailed throughout Presidential Executive Orders and
within the CAA. Though Presidential Executive Orders are not binding by
law, they foster an open, transparent rule-making process. For example,
Executive Order 12866 states, ``The American people deserve a
regulatory system that works for them, not against them: a regulatory
system that . . . improves the performance of the economy without
imposing unacceptable or unreasonable costs on society.'' Accordingly,
the Order requires federal agencies, including EPA, to develop
regulations ``in the most cost effective manner'' and to ``adopt a
regulation only upon a reasoned determination that the benefits of the
intended regulation justify its costs.'' An additional $1.2 billion in
costs under EPA's proposal in exchange for no perceptible change in
visibility does not qualify as ``a reasoned determination that the
benefits of the intended regulation justify its costs.''
EPA's proposed action will result in over $170 million annual
adverse economic impact, well over the $100 million annual threshold
identified in Executive Order 12866. EPA failed to properly consider
material effects its proposed action will have on the economy,
productivity, competition, and jobs. By forcing unnecessarily expensive
technologies, electricity rates will rise even further, putting
additional strain on businesses and millions of customers that receive
electricity from the generating stations in Wyoming.
Response: EPA disagrees with this comment. As explained elsewhere,
this action does not fit within the definition of Executive Order
12866. The Order defines a ``regulation'' or ``rule'' as an ``agency
statement of general applicability.'' Executive Order 12866(3)(d).
Here, EPA's action was individually tailored for a limited number of
BART eligible sources in Wyoming, and thus is not generally applicable
and not governed by Order 12866. Moreover, as explained in more detail
in the BART section, EPA took the cost of compliance into consideration
when making its BART determinations to ensure the rule's requirements
are beneficial and not unduly burdensome.
11. Consideration of Existing Controls
Comment: Several commenters asserted that EPA did not properly take
into account the existing pollution control technology in use at the
BART-eligible EGUs, as required by CAA section 169A(g)(2) and the BART
[[Page 5104]]
Guidelines. These commenters alleged that EPA was required to consider
updated combustion controls, which were installed to comply with
Wyoming's regional haze SIP, by adjusting the baseline emissions rate
for each facility to account for any emissions reductions that have
been achieved since the 2001-2003 baseline period. The commenters
suggested that had EPA relied on available 2011-2012 emissions data,
which reflect the NOX reductions achieved by some of these
newly installed controls, the cost-effectiveness values for SNCR and
SCR would have been higher, while the visibility improvement associated
with SNCR and SCR would have been lower.
For example, one commenter stated that the baseline emission rate
for NOX in 2001-2003 was 0.27 lbs/MMBtu at Laramie River,
but that the emission rate had dropped to 0.19 lb/MMBtu after the
installation of over-fire air and low NOX burners. This
commenter asserted that, had EPA adjusted the baseline to the latter
emission rate, the average cost-effectiveness for SNCR would be between
$6,967/ton and $7,014/ton, while the average cost-effectiveness for SCR
would be between $8,531/ton and $9,048/ton. Based on these values, the
commenter argued that neither SNCR nor SCR is cost-effective and
therefore both technologies should be eliminated as NOX BART
for Laramie River.
Another commenter pointed to other EPA regional haze actions where
EPA adjusted baseline emissions to account for recently installed
controls, such as EPA's final actions on the Arizona regional haze SIP,
77 FR 72512, and Montana regional haze FIP, 77 FR 57864. This commenter
argued that because EPA had adjusted baseline emissions for some
Arizona and Montana EGUs to account for controls recently installed to
satisfy consent decrees obligations or CAA requirements unrelated to
regional haze, EPA was required to do so for Wyoming's EGUs as well.
One commenter submitted additional comments, after the close of the
public comment period, in response to the decision of the U.S. Court of
Appeals for the Eighth Circuit in North Dakota v. EPA, 730 F.3d 750
(8th Cir. 2013). This commenter again asserted that EPA had failed to
consider the low NOX burners and over-fire air the commenter
had installed at its facilities to comply with the Wyoming regional
haze SIP. The commenter argued that EPA's alleged failure to consider
these controls violates the holding in North Dakota, that ``any
existing pollution control technology'' includes all existing controls,
including those that are voluntarily installed by the source. Moreover,
the commenter explained, the low NOX burners and over-fire
air at its facilities were not voluntary controls because they were
installed to meet CAA requirements, were federally enforceable, and
were incorporated into the Wyoming regional haze SIP.
A final commenter also submitted late comments in response to the
decision in North Dakota and the previous commenter's letter. This
commenter argued that the North Dakota decision does not require EPA to
account for existing controls by factoring their associated emissions
reductions into baseline emissions. The commenter explained that using
a consistent baseline prevents certain sources from claiming credit for
minor emission reduction measures taken in the midst of the ongoing
regional haze planning process, thereby making more stringent controls
appear less beneficial. The commenter also explained that the fixed
baseline period of 2001-2003 allows EPA to make ``apples-to-apples''
comparisons of the cost-effectiveness and visibility benefits of
evaluated technologies across all BART sources. The commenter pointed
out that EPA's method of evaluating combustion controls as a BART
option, not as part of the emission baseline, was identical to the
approach that Wyoming and the sources themselves had taken in their own
BART analyses. The commenter argued that this approach is correct
because it ensures that the emissions reductions associated with
existing controls installed after the baseline period are evaluated in
the BART analysis. It also factors the cost of such controls into the
source's compliance costs, rather than assuming that such costs are
zero simply because they already have been incurred. Finally, the
commenter asserted that even if EPA were to adjust the baseline
emissions for the EGUs in question, SCR would still be BART for all of
the EGUs.
Response: One of the statutory factors EPA is to consider is ``any
existing pollution control technology in use at the source.'' 42 U.S.C.
7491(g)(2). The CAA does not specify how states or EPA must ``take into
consideration'' this factor. The BART Guidelines provide little
additional guidance, stating only that ``[f]or emission units subject
to a BART review, there will often be control measures or devices
already in place. For such emission units, it is important to include
control options that involve improvements to existing controls and not
to limit the control options only to those measures that involve a
complete replacement of control devices.'' 40 CFR part 51, app. Y, at
IV.D.1.6. Consequently, we believe that states and EPA have
considerable discretion in how they consider existing controls in use
at a source, so long as that consideration is explained and reasonable.
Ultimately, states or EPA should consider the totality of the
circumstances (e.g., the purpose of any existing controls, when and why
they were installed, compatibility with other control options,
enforceability, and other pertinent factors) in determining how they
will evaluate existing controls in a BART analysis.
For example, one way in which a state or EPA can consider existing
controls, as contemplated by the BART Guidelines, is by evaluating
whether additional control options are technologically compatible with
a source's existing controls, or whether the presence of the existing
controls would render the installation of some additional control
options infeasible. In the case of NOX, the presence of
existing combustion controls at a source, such as low NOX
burners or over-fire air, does not impact the feasibility of installing
post-combustion controls, such as SNCR or SCR. Consequently, EPA
reasonably determined in this instance that the presence of existing
combustion controls at several of the BART-eligible EGUs would not
preclude the installation of either SNCR or SCR.
Pointing to our regional haze actions in Arizona and Montana,
several of the commenters asserted that EPA was required to consider
existing controls by adjusting the baseline emissions of several
sources to account for reductions achieved after the baseline period.
We disagree. The BART Guidelines recommend that baseline emissions
should be ``based upon actual emissions from a baseline period.'' 40
CFR part 51, app. Y, at IV.D.4.d.1. While the BART Guidelines allow
states or EPA to adjust baseline emissions to take into account
projections of ``future operating parameters'' by making such
assumptions into enforceable limits, id. at IV.D.4.d.2, the BART
Guidelines are silent as to how reductions resulting from the post-
baseline installation of controls should be treated. One way to take
account of such reductions is to update the baseline, as we did in our
regional haze actions for Arizona and Montana. In those rulemakings, we
determined that updating the baseline was appropriate because several
sources had recently installed combustion controls to comply with
consent-decree obligations and acid-rain requirements, while another
source had changed its coal supply. The fact that these controls were
installed to comply with other CAA requirements heavily informed
[[Page 5105]]
EPA's decision to update the sources' baseline emissions. As we
explained in our Arizona action, however, ``an `updated baseline' might
not be appropriate in all instances. For instance, if it appeared that
controls had been installed early in order to avoid a more stringent
BART determination, it would presumably not be appropriate to use a
baseline representing these new controls.'' 72 FR 72526.
We believe that this is one such instance. First, unlike in Arizona
and Montana, the sources did not install the combustion controls in
question to comply with other CAA requirements. Rather, as stated above
in the comment, the sources installed the controls to comply with
Wyoming's selection of BART in its regional haze SIP. This distinction
is important because, by their very nature, baseline emissions should
be ``a realistic depiction of anticipated annual emissions'' before the
installation of BART. 40 CFR part 51, app. Y, at IV.D.4.d. Thus, while
baseline emissions can take into account newly installed controls and
in some cases future operating parameters, baseline emissions still
must represent a pre-BART scenario so that the cost-effectiveness and
visibility benefits of all potential BART control options can be
evaluated from a consistent benchmark. Indeed, it would be passing
strange for EPA to update the commenters' baseline emissions to
incorporate emission reductions that they admittedly achieved to comply
with BART. Doing so would bias EPA's analysis of additional control
options by giving the commenters credit for emissions reductions
attributable to BART, but treating the costs they incurred to achieve
those reductions as if they had never occurred.
Second, we note that the Wyoming regional haze SIP did not require
compliance with BART until five years after EPA's approval of the SIP.
At the time the sources installed the combustion controls, EPA had not
yet acted upon Wyoming's regional haze SIP, and the sources had no way
of knowing whether EPA would ultimately approve or disapprove Wyoming's
BART determinations. Thus, it appears that the sources' decision to
install the combustion controls early may have been motivated by an
intent to avoid the possibility of a more stringent BART determination
by EPA under the theory now advanced in the comment. To be consistent
with our statements in the Arizona regional haze action, we believe
that it would have been inappropriate for EPA to have ``taken into
consideration'' the newly installed combustion controls at the
commenters' facilities by updating the baseline in this case.
Nonetheless, EPA recognizes that we must ``take into
consideration'' all existing controls to comply with the CAA, and have
therefore taken the sources' existing combustion controls into
consideration in other ways. For example, in addition to considering
whether the source's existing combustion controls were compatible with
the installation of post-combustion controls, we also used the source's
current NOX emission rates when we evaluated the size,
design, and reagent/catalyst cost of SNCR and SCR. For example, in the
case of Laramie River, we did not use the baseline emission rate of
0.27 lbs/MMBtu, but rather the current emission rate of 0.19 lb/MMBtu
that appropriately reflects the installation of over-fire air and low
NOX burners. Due to the lower NOX emission rate,
the size of the SNCR and SCR systems and the amount of reagent/catalyst
necessary to operate them are lower than if we had simply assumed the
baseline emission rate.
Moreover, we do not believe that our action is inconsistent with
the Eighth Circuit's decision in North Dakota. In our regional haze
action for North Dakota, we refused to consider the
DryFiningTM control technology in use at Coal Creek Station
when we promulgated a FIP. We argued to the court that the CAA did not
require states or EPA to consider controls that were voluntarily
installed after the baseline period. The court rejected this position,
holding that ``EPA's refusal to consider the existing pollution control
technology in use at the Coal Creek Station because it had been
voluntarily installed was arbitrary and capricious.'' North Dakota,
2013 U.S. App. LEXIS 19442, at*30. The court explained that ``any
existing pollution control technology'' included even voluntarily
installed controls. However, the court did not opine as to how existing
controls must be considered. Here, EPA reasonably considered the
existing controls at the BART-eligible sources in the several ways
described above. North Dakota does not require us to ``take into
consideration'' existing controls by adjusting baseline emissions,
which would have been inappropriate in this instance.
Finally, while we acknowledge the supportive comments from the
final commenter on this issue and agree with many of the points that
were made, we decline to require SCR at all of the BART-eligible EGUs,
for reasons explained elsewhere in this document.
12. Consent Decree
Comment: As it had on other SIPs, EPA neglected to act on Wyoming's
SIP, and as a result exposed itself to liability for violating Section
110(k) of the CAA. See 42 U.S.C. 7410(k)(2), (3) (setting deadlines for
EPA action on SIPs). Wyoming could have sued EPA for failing to take
action on Wyoming's SIP, but in the spirit of cooperation, elected not
to. Instead, special interest groups sued EPA for its failure to comply
with the Act. See Compl., WildEarth Guardians v. Jackson, No. 1:11-cv-
00001-CMA-MEH (D. Colo. Jan. 2, 2011). Wyoming did not participate in
this litigation for two reasons: First, Wyoming was not aware of the
litigation until EPA published the proposed consent decree, 76 FR 34983
(June 15, 2011); and, second, EPA has repeatedly opposed state attempts
to participate in litigation that impacts the processing of SIPs, see,
e.g., Def. Opp. to North Dakota's Motion to Intervene, WildEarth
Guardians v. Jackson, No.4:09-CV-02453-CW (N.D. Cal. Oct. 20, 2011).
The special interest groups' litigation, in turn, has driven EPA's
approach to Wyoming's SIP. The litigation has established arbitrary
deadlines for EPA to act on Wyoming's SIP, which EPA and the special
interest groups have repeatedly extended for their convenience. Not
once has EPA consulted the State on these deadlines. More troubling,
through settlement of that litigation, EPA has committed to particular
courses of action on Wyoming's SIP. EPA has cut Wyoming out of the
cooperative federalism Congress intended to guide the regional haze
program.
This dubious approach to implementing the CAA harms states. The
unprecedented influence the special interest groups have exerted over
EPA's treatment of Wyoming's SIP, coupled with EPA's effort to conceal
its communications with those groups, lead a reasonable observer to
seriously question the objectivity of EPA's proposed action on
Wyoming's SIP.
The commenter also asserted that the EPA let sue-and-settle tactics
pervert what is typically a cooperative process. Nongovernmental groups
should not be allowed to coerce an agency into setting policy as a
result of litigation. Wyoming considers this an attack on states'
rights, which does nothing to further the partnership between EPA and
Wyoming, especially when Wyoming can't participate in those
discussions.
Response: We disagree with commenter's assertions. The Act provides
citizens with the right to sue EPA when EPA fails to meet a statutory
[[Page 5106]]
deadline, 42 U.S.C. 7604(a)(2), and courts have the authority to
establish a remedy that sets new deadlines and compels EPA to do what
Congress required. Id. Section 7604(a). When EPA is confronted with
such suits, it is reasonable and proper for EPA, working with the
Department of Justice, to decide that it is in the public interest, and
a more efficient use of executive and judicial branch resources, to
settle such cases rather than litigate them. Congress recognized that
EPA has authority to settle cases, and directed EPA to provide public
notice and an opportunity to comment on proposed consent decrees before
finalizing them. Id. Section 7413(g).
As explained in the Introduction section of this document, the
consent decree of which the commenter complains was the result of a
citizen suit that sought to compel EPA to approve SIPs or promulgate
FIPs to meet long overdue regional haze requirements.\72\ The State of
Wyoming did not submit its regional haze implementation plan in a
timely fashion as required by the CAA and EPA's regulations. Facing
substantial legal risk, EPA reasonably negotiated a settlement
resulting in a consent decree that set new deadlines for EPA to take
actions required by the Act.\73\ The Consent Decree was published in
the Federal Register as is required under the CAA section 113(g) and
provided 30 days for public comment. See 76 FR 34983 (June 6, 2011).
For Wyoming, EPA's obligations to fully approve SIPs or promulgate a
FIP were now due six years after the original 2007 deadline for the
submission of regional haze SIPs. The consent decree was also subject
to district court review before its entry. Neither the commenters nor
any other party objected to the deadlines established for EPA's action
on the Wyoming regional haze SIP. The United States District Court for
Colorado found the terms of the consent decree reasonable.
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\72\ January 2, 2011 a Complaint was filed against EPA in the
federal district court for the District of Colorado seeking
declaratory and injunctive relief under the Clean Air Act due to
EPA's failure to meet regulatory and statutory deadlines for the
regional haze implementation plan. See WildEarth Guardians v.
Jackson, Case No. 11-cv-0001-CMA-MEH (D. Colo.).
\73\ The EPA resolved this complaint by means of a settlement
agreement that was memorialized in a Consent Decree that was entered
by the Court on June 6, 2011 (the ``Consent Decree'').
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The commenter's argument that EPA used these consent decree
deadlines and ``has committed to particular courses of action on
Wyoming's SIP'' with regard to the Final Rule is without merit. The
consent decree did not limit or change EPA's substantive rulemaking
authority or discretion in any way. Rather, the consent decree
specifically permitted EPA to satisfy its obligations either by
approving the States' regional haze SIPs or by promulgating a FIP. EPA
also provided more than 70 days from the date of publication in the
Federal Register for interested parties to submit comments on the
proposed rule, longer than the 30-day public comment period required by
the Act. 42 U.S.C. 7607(h). EPA obtained several extensions of the
consent decree deadline for Wyoming to provide the Agency with adequate
time to conduct the rulemaking.\74\ For all these reasons, neither the
consent decree nor the deadlines it imposed rendered EPA's Final Rule
arbitrary, capricious, or contrary to law.
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\74\ EPA routinely notifies the states of these extensions. For
example, on December 11, 2012, Region 8 Air Program Director Carl
Daly called Wyoming DEQ's Steve Dietrich and his staff, to let them
know the Agency had submitted a motion to the Court to re-propose
the 309(g) rule. Mr. Daly also contacted Mr. Dietrich on March 26,
2013 to let the State know EPA was working on further extensions, as
the Agency needed additional time to consult with our headquarters
offices.
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Finally, EPA did not rely on information that was not in the docket
for this rule. Therefore, contrary to commenter's assertions, all
information relied upon has been disclosed.
Comment: EPA quickly entered into a settlement agreement to resolve
the special interest groups' litigation, rather than defend its actions
and honor Wyoming's patience with EPA's inaction. In settling the
litigation, EPA agreed to take final action on Wyoming's SIP by April
15, 2012. Consent Decree, WildEarth Guardians v. Jackson, No. 1: 11-cv-
00001-CMA-MEH, at 4, '1]6 (D. Colo. Separt 27, 2011) (WildEarth
Guardians). Recognizing that it still could not meet its statutory
obligation to act on Wyoming's SIP, EPA persuaded the special interest
groups to extend that deadline thirty days to May 15, 2012. Stip. to
Extend Four Deadlines in Consent Decree at 3, ~ 6, WildEarth Guardians,
(D. Colo. Jan. 10, 2012).
On June 2, 2012, eighteen months after Wyoming submitted its SIP,
EPA proposed to partially approve and partially disapprove the SIP. 77
FR 33022. But, as a result of EPA's unlawfully delayed action,
Wyoming's SIP became complete by operation of law. See 42 U.S.C.
7410(k)(l)(B). Accordingly, EPA cannot now propose to disapprove
Wyoming's SIP on the grounds that it lacks information. To do otherwise
is to render Section 110(k)(l)(B) meaningless.
Response: EPA disagrees with this comment. First, the commenter
offers no grounds on which EPA could have defended the cited
litigation, which involved mandatory statutory deadlines under the Act.
Second, EPA disagrees with the commenter's interpretation of CAA
section 110(k)(l)(B). Under the CAA, EPA's SIP review is a two-step
process. See CAA Section 110(k). First, within six months of a SIP
submission, EPA must make a threshold ``completeness determination'' to
determine whether the SIP contains certain ``minimum criteria''
designated by EPA as ``the information necessary to . . . determine
whether the plan submission complies with the provisions of [the
CAA].'' See id. Section 110(k)(1)(A), (B). These minimum criteria are
listed in Appendix V to 40 CFR. Part 51 and include a relatively short
list of eight ``Administrative Materials'' and nine ``Technical
Support'' requirements, such as evidence that the state properly
adopted the SIP and technical demonstrations that allow EPA to evaluate
compliance with the substantive requirements of the CAA. See 40 CFR.
part 51, App. V. If EPA fails to make the completeness determination
within six months, the SIP is deemed complete by operation of law. See
CAA Section 110(k)(1)(C).
Importantly, however, a determination of completeness, either by
EPA or by operation of law, does not mean that the SIP has been
approved as compliant with the substantive requirements of the CAA.
Indeed, Appendix V does not include any substantive requirements, such
as the requirement that regional haze SIPs include a five-factor BART
analysis. These requirements are included elsewhere in the CAA, the
Haze Rule, and the BART Guidelines.
Instead, EPA evaluates SIPs for compliance with the substantive
requirements in the second step of EPA's review, which EPA must
complete within one year after the SIP is determined to be complete by
EPA or deemed complete by operation of law. See CAA Section 110(k)(2),
(3), & (l) (providing a one-year deadline by which EPA must determine
whether the SIP ``meets all of the applicable requirements'' or
``interferes with any applicable requirement'' of the Act); see also
NRDC v. Browner, 57 F.3d 1122, 1126 (D.C. Cir. 1995) (``Under the two-
stage procedure established in [section] 110(k), EPA first makes an
essentially ministerial finding of completeness, a process taking at
most six months. By contrast, the plan approval process may take up to
twelve months due to the more extensive technical analyses necessary to
ensure that the SIP meets
[[Page 5107]]
the Act's substantive requirements.'' (emphasis added)). Accordingly, a
completeness determination in Step 1 does not deprive EPA of authority
to disapprove a SIP in Step 2 for failure to comply with substantive
requirements of the CAA, the Haze Rule, and the BART Guidelines.
Instead, a completeness determination merely triggers EPA's duty to
evaluate the substance of a SIP in the first instance and either
approve or disapprove the SIP as necessary within one year. As
explained above, EPA has authority to substantively review states'
five-factor BART analyses in Step 2, and must disapprove a SIP if its
analysis fails to comply with the requirements of the CAA, the Haze
Rule, or the BART Guidelines. See Oklahoma, 723 F.3d at 1207-10. Thus,
the comment is incorrect in stating that EPA's action here renders
section 110(k)(1)(B) meaningless.
Moreover, courts have repeatedly stated that EPA does not lose its
statutory authority to act under the CAA for a failure to meet its
statutory deadline and that the proper remedy in the case of delay is
for a party to seek an order to compel action. Oklahoma v. EPA., 723
F.3d 1201, 1224 (10th Cir. 2013) (explaining that although the CAA
``undoubtedly requires that the EPA promulgate a FIP within two years,
it does not stand to reason that it loses its ability to do so after
this two-year period expires''); Montana Sulphur & Chem. Co. v. EPA.,
666 F.3d 1174, 1190 (9th Cir. 2012) cert. denied, 133 S. Ct. 409,
(2012) (explaining that although CAA has an ``explicit deadline . . .
it does not follow that the agency loses authority to act if it fails
to meet that deadline''); Gen. Motors Corp. v. United States, 496 U.S.
530, 541 (1990) (holding EPA does not lose authority under CAA because
``other statutory remedies are available when EPA delays action on a
SIP revision''); see also Brock v. Pierce Cnty., 476 U.S. 253, 260
(1986) (holding that when ``there are less drastic remedies available
for failure to meet a statutory deadline . . . courts should not assume
that Congress intended the agency to lose its power to act'').
Comment: Two months after the period for commenting on EPA's 2012
proposal closed, EPA and the special interest groups again modified the
consent decree to allow EPA additional time to take action on Wyoming's
SIP. See Stip. To Extend Deadline in Consent Decree., WildEarth
Guardians (D. Colo. Oct. 3, 2012). Then, two months after extending the
deadline for action on Wyoming's SIP, EPA asked the court to again
extend EPA's deadline, this time until September 27, 2013. Def.
Unopposed Mot. To Modify Two Deadlines in Consent Decree, at 1,
WildEarth Guardians (Dec. 10, 2012).
As grounds for the request, EPA cited the special interest groups'
comments, which EPA asserted ``necessitate[d] re-proposal of the
rule.'' Id. at 3-4. The court, in turn, granted EPA's request. Order To
Modify Consent Decree, WildEarth Guardians (Dec. 13, 2012). Even after
extending its deadline to take action on Wyoming's SIP three times, EPA
still needed more time. So, on March 25, 2013, EPA and the special
interest groups again agreed to extend EPA's deadline for action on
Wyoming's SIP. Stip. To Extend Deadlines in Consent Decree, WildEarth
Guardians (March 25, 2013) (extending deadline until Nov. 21, 2013).
Seemingly as a condition for obtaining the special interests groups'
consent to the extension, EPA ostensibly agreed to a timetable for
Wyoming sources to install emission controls faster than what Wyoming
proposed. Compare id. at 2, ~ 6 (``EPA will propose to determine, for
each source subject to BART, the period of time for BART compliance
that is as expeditious as practicable''), with 78 FR 34778 (``We
propose that PacifiCorp meet our proposed emission limit . . . as
expeditiously as practicable, but no later than five years after EPA
finalizes action''). Had Wyoming known when EPA proposed the consent
decree in 2011 that EPA would commit to a particular course action on
Wyoming's SIP, rather than just a date for taking some unspecified
action, Wyoming would have sought to intervene in the litigation.
Response: EPA disagrees that it committed to any particular course
of action in the Consent Decree. The Consent Decree only specified a
timetable for EPA to promulgate rules consistent with its statutory
obligations under the CAA, but did not commit the EPA to any particular
course of action not already required by law. In fact, the Consent
Decree specifically states: ``Nothing in this Consent Decree shall be
construed to limit or modify any discretion accorded EPA by the CAA or
by general principles of administrative law in taking the actions which
are the subject of this Consent Decree, including the discretion to
alter, amend, or revise any final actions contemplated by this Consent
Decree.''
We disagree with the commenter's allegations that EPA agreed in the
Consent Decree to a timetable for Wyoming sources to install BART
controls faster than what Wyoming proposed in its SIP. Paragraph 6 of
the Stipulation To Extend Deadlines in Consent Decree, WildEarth
Guardians (March 25, 2013) specifies that:
By May 23, 2013, EPA shall sign a notice of re-proposed
rulemaking in which it proposes approval of a SIP, promulgation of a
FIP, partial approval of a SIP and promulgation of a partial FIP, or
approval of a SIP or promulgation of a FIP in the alternative, for
the State of Wyoming, to meet the regional haze implementation plan
requirements that were due by December 17, 2007, under 40 CFR
51.309(g). In its re-proposal, EPA will propose to determine, for
each source subject to BART, the period of time for BART compliance
that is as expeditious as practicable, as required by 42 U.S.C.
Section 7491. (emphasis added).
Commenter neglects to include the last phrase in this provision in
its comment--``as required by 42 U.S.C. Section 7491.'' The Consent
Decree required EPA to meet that CAA requirement.\75\ Therefore, the
Consent Decree mirrors and is consistent with the CAA BART
requirements.
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\75\ Additionally, the CAA defines the term ``as expeditiously
as practicable'' to mean ``as expeditiously as practicable but in no
event later than five years after the date of approval of a plan
revision under this section (or the date of promulgation of such a
plan revision in the case of action by the Administrator under
section 110(c) [42 USCS Section 7410(c)] for purposes of this
section).'' 42 U.S.C. 7491(g)(4).
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Finally, we are acting consistently with the Act and the RHR, as we
discuss in detail elsewhere throughout this final action.
13. Monitoring, Recordkeeping and Reporting
Comment: EPA proposed a FIP for all monitoring, recordkeeping, and
reporting requirements related to BART and reasonable progress sources
for which there is a SIP or FIP emissions limit. EPA notes that the
State's monitoring, recordkeeping, and reporting language in their SIP
includes references to WAQSR chapters that EPA has not approved as part
of the SIP and erroneously concludes that this means Wyoming's
requirements are not federally enforceable.
Wyoming does not concur with EPA's findings. The monitoring,
recordkeeping and reporting language in the State's regional haze SIP
is taken directly from air quality permits issued under the SIP-
approved permitting provisions in Chapter 6, Section 2 of the WAQSR,
and are therefore federally enforceable. See 40 CFR 52.2620(c)(1). When
drafting the monitoring, recordkeeping, and reporting requirements, the
State incorporated the requirements of 40 CFR part 60 for trona
facilities and for EGUs. Specifically, 40 CFR part 60 subparts D and Da
were incorporated into the monitoring conditions for each
[[Page 5108]]
BART permit. In the case of EGUs, by relying upon subpart D and Da, the
State is also incorporating the requirements of 40 CFR part 75, since
the monitoring provisions of subpart Da refer back to the continuous
emissions monitor requirements under the Acid Rain Program codified in
40 CFR part 75.
While Wyoming allows for data substitution using the methodology
prescribed in 40 CFR part 75, this is only applicable to annual
emissions to account for periods when the continuous emissions monitor
is down and the emissions unit continues to operate. Substituting data
for these operating periods is more conservative than removing them
altogether. EPA asserts that there are numerous clarifications and
rewording needed; however, these monitoring, recordkeeping, and
reporting requirements are currently in effect for PacifiCorp and Basin
Electric units, and the companies are able to demonstrate compliance
using them. Furthermore, the recordkeeping and reporting requirements
contained in Chapter 5, Section 2 of the WAQSR are modeled after 40 CFR
part 60, as these provisions are delegated to the State by EPA. See 40
CFR 60.4(c). While WAQSR Chapter 5, Section 2 is not part of Wyoming's
SIP, the requirements therein are analogous to the federal New Source
Performance Standards requirements and are made federally enforceable
through incorporation by a Chapter 6, Section 2 BART permit and EPA's
delegation to Wyoming.
Since these monitoring, recordkeeping, and reporting requirements
are contained in federally enforceable permits and the affected
companies are already able to demonstrate compliance with the BART
emissions limits using them, Wyoming concludes that it did include
appropriate and adequate monitoring, recordkeeping, and reporting
requirements in the SIP.
Response: EPA disagrees with this comment. As discussed above in
this section, EPA's approach in this action is entirely consistent with
section 169A(b)(2) which, as we wrote when we promulgated the BART
Guidelines, ``provides that EPA must require SIPs to contain emission
limits, schedules of compliance, and other measures as may be necessary
to make reasonable progress towards meeting the goal'' (emphasis
added). 70 FR 39120. The regulations require that the states ``must
submit an implementation plan containing emission limitations
representing BART.'' 40 CPR 51.308(e). The Guidelines require that
states ``must establish an enforceable emission limit for each subject
emission unit at the source and for each pollutant subject to review
that is emitted from the source.'' 70 FR 39172. CAA section
110(a)(2)(A) also requires that SIPs shall ``include enforceable
emission limitations . . . as may be necessary or appropriate to meet
the applicable requirements of [the Act].''
Therefore, EPA disagrees that the use of BART permits to implement
the monitoring, recordkeeping, and reporting necessary to ensure
compliance with BART emission limitations is adequate under the CAA. In
addition, in response to another comment, we are removing the
requirements for annual emission limits for BART and reasonable
progress sources. (See section IV.C.3 of this rulemaking). Thus, the
point raised by the commenter pertaining to data substitution no longer
applies to our final action.
B. Modeling
1. General Comments
Comment: One commenter stated that EPA must re-evaluate its method
for assessing visibility impacts from wildfires or states will never be
able to achieve natural background goals. The commenter went on to say
that EPA should (1) eliminate the impacts from fire from the annual
contribution to the deciview analysis or (2) properly incorporate it
into the natural background equation to establish a glide path states
can achieve. The commenter provided graphical data from the Interagency
Monitoring of Protected Visual Environments (IMPROVE) network to show
the contributions to light extinction from organic carbon, elemental
carbon, and nitrate.
Response: EPA disagrees that we must re-evaluate our methods in
this action. However, EPA agrees that wildfires can be an important
source of visibility impairment, especially in the western states
during the summer wildfire season. EPA recognized that variability in
natural sources of visibility impairment causes variability in natural
haze levels as described in its ``Guidance for Estimating Natural
Visibility Conditions Under the Regional Haze Rule.'' \76\ The preamble
to the BART guidelines (70 FR 39124) describes an approach used to
measure progress toward natural visibility in Mandatory Class I areas
that includes a URP toward natural conditions for the 20 percent worst
days and no degradation of visibility on the 20 percent best days. The
use of the 20 percent worst natural conditions days in the calculation
of the URP takes into consideration visibility impairment from wild
fires, windblown dust and other natural sources of haze. The ``Guidance
for Estimating Natural Visibility'' also discusses the use of the 20
percent best days and the 20 percent worst days estimates of natural
visibility, provides for revisions to these estimates as better data
becomes available, and discusses possible approaches for refining
natural conditions estimates.\77\ The commenter does not identify any
way in which EPA's action was inconsistent with this guidance or the
RHR.
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\76\ Guidance for Estimating Natural Visibility Conditions Under
the Regional Haze Rule, Document No. EPA-R09-OAR-2012-0345-0003-B9,
U.S. Environmental Protection Agency, September 2003. https://www.epa.gov/ttncaaa1/t1/memoranda/rh_envcurhr_gd.pdf, page 1-1:
``Natural visibility conditions represent the long-term degree of
visibility that is estimated to exist in a given mandatory Federal
Class I area in the absence of human-caused impairment. It is
recognized that natural visibility conditions are not constant, but
rather they vary with changing natural processes (e.g., windblown
dust, fire, volcanic activity, biogenic emissions). Specific natural
events can lead to high short-term concentrations of particulate
matter and its precursors. However, for the purpose of this guidance
and implementation of the regional haze program, natural visibility
conditions represents a long-term average condition analogous to the
5-year average best- and worst-day conditions that are tracked under
the regional haze program.''
\77\ Ibid., pages 3-1 to 3-4.
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Comment: At the hearing, Governor Mead and representatives of
Wyoming, as well as industry representatives, argued that worsening
haze has been caused by wildfires.
Response: We acknowledge the commenter's points on wildfires,\78\
and that they can be an important source of visibility impairment,
especially in the western states during the summer wildfire season. As
discussed in more detail above and in our proposed notice, EPA
recognizes that variability in natural sources of visibility impairment
cause variability in natural haze levels and provided approaches to
address this in the preamble to the BART guidelines (70 FR 39124).
However, while we acknowledge that wildfires contribute to regional
haze, the BART CALPUFF
[[Page 5109]]
modeling has demonstrated that Wyoming's BART sources are also
significant contributors to regional haze.
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\78\ 78 FR at 34767 (``Table 28 also shows that Wyoming is not
meeting the URP to meet natural visibility conditions by 2064. In
this case, 40 CFR 51.308(d)(1)(ii) requires the State to
demonstrate, based on the four factors in 51.308(d)(1)(i)(A), that
the RPGs established in this SIP are reasonable for this planning
period and that achieving the URP in this planning period is not
reasonable. In its demonstration, the State cited many reasons why
meeting the URP was not reasonable, including the following. First,
emissions from natural sources greatly affect the State's ability to
meet the 2018 URP. As discussed earlier, WEP data shows that
emissions of OC, EC, PM2.5, and PM10 come
mainly from natural or non-anthropogenic sources, such as natural
wildfire and windblown dust.'')
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Comment: Although the various BART application analyses conducted
by Wyoming for PacifiCorp's BART units note that Wyoming conducted a
``comprehensive visibility analysis covering all three visibility
impairing pollutants,'' the analyses also state: ``While visibility
impacts were addressed in a cumulative analysis of all three
pollutants, Post-Control Scenario B is directly comparable to Post-
Control Scenario A as the only difference is directly attributable to
the installation of SCR. Subtracting the modeled values from each other
yield the incremental visibility improvement from SCR.'' In other
words, Wyoming clearly considered--and made available to EPA--the very
specific NOX information that EPA claims it ``was not
possible for EPA, or any other party, to ascertain.'' Simply claiming
it ``was not possible for EPA'' to ascertain results from available
information does not justify EPA in rejecting Wyoming's NOX
BART determinations. Wyoming had considered SCR-specific visibility
information. EPA cannot use the alleged lack of this information to
justify requiring SCR as BART.
Response: We disagree with all aspects of this comment. Although a
state is not required by EPA's regulations to model the visibility
impacts from all possible control alternatives if the state selects the
most stringent controls available as BART that is not what happened
here. Wyoming rejected SNCR and SCR as BART without adequately
assessing the visibility benefits of these control strategies. Given
the cost effectiveness of these controls, the State's failure to
consider visibility impacts was not reasonable and was inconsistent
with the CAA and regulations. EPA was compelled to perform additional
CALPUFF modeling for NOX BART determinations to allow for
consideration of visibility impacts. For example, while Wyoming took
into consideration the degree of visibility improvement for other BART
NOX control options for the PacifiCorp EGUs, such as SCR,
the State did not do so for SNCR. The visibility improvement for SNCR
was neither provided in the State's SIP nor made available to the EPA.
Wyoming did not assess the visibility improvement of SNCR despite
having found it to be a technically feasible control option, and having
considered a number of the other statutory factors for SNCR, such as
costs of compliance and energy impacts. Given that nothing in the
State's analysis suggested that SNCR was inappropriate, Wyoming's
failure to consider the visibility improvement of SNCR is clearly in
conflict with the statutory requirements set forth in section
169A(g)(2) of the CAA, which require that states take into
consideration ``the degree of improvement in visibility which may
reasonably be anticipated to result from the use of such technology.''
Since Wyoming did not do so, EPA conducted additional CALPUFF modeling
to fill this gap in the State's visibility analysis.
In addition, as stated in our 2012 proposed rule and in our 2013
re-proposal, it was not possible for EPA, or any other party, to
ascertain the visibility improvement from the NOX control
options as emission reductions for multiple pollutants were modeled
together. That is, since the visibility improvement for each of the
State's control scenarios was due to the combined emission reductions
associated with SO2, NOX, and PM controls, it was
not possible to isolate what portion of the improvement was
attributable to the NOX controls alone. For this reason, in
the modeling conducted by EPA, we held SO2 and PM emission
rates constant (reflecting the ``committed controls'' for those
pollutants identified by Wyoming), and varied only the NOX
emission rate. This allowed us to isolate the degree of visibility
improvement attributable to the NOX control option.
We do agree that Wyoming's analysis allows for the incremental
comparison between two post-control options (Post-Control Scenario A
and Post-Control Scenario B). However, the BART Guidelines require more
than this, stating that you should ``[a]ssess the visibility
improvement based on the modeled change in visibility impacts for the
pre-control and post-control emission scenarios.'' \79\ That is, it is
not sufficient to assess only the incremental visibility between
control options, you must also assess the visibility improvement of
each control option relative to the pre-control scenario. Therefore,
Wyoming clearly did not assess visibility improvement in a manner
consistent with that explicitly prescribed by the BART Guidelines.
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\79\ 40 CFR 39170.
---------------------------------------------------------------------------
In summary, while States may have some discretion in how to
determine visibility impacts, Wyoming did not fulfill the basic
statutory requirement to consider the visibility improvement of each of
the NOX control options they identified as technically
feasible. They also did not assess visibility improvement in a manner
consistent with the approach prescribed by the BART Guidelines. As a
result, EPA concluded it would be appropriate to conduct additional
CALPUFF modeling.
Comment: The egregiousness of EPA's actions becomes even more
apparent when comparing EPA's conclusions regarding cost and visibility
impacts for certain of PacifiCorp's BART units against the cost and
visibility impact conclusions reached by Wyoming for the same units.
Table 2 in our comments provides a comparison between Wyoming's modeled
delta deciview improvements and EPA's delta deciview improvements based
on the ``new information'' EPA claims it has developed. Recognizing
EPA's conclusion that one deciview is barely perceptible to the human
eye and considering the inaccuracies and limitations of the model
inputs and versions of the visibility models being used, there is no
significant difference between Wyoming's results and EPA's results.
Additionally, without any ``bright line'' test regarding the amount of
visibility improvement that justifies a given control device, EPA
cannot show that these insignificant differences would have any impact
on the BART determinations for PacifiCorp's BART units.
Response: With respect to the ``bright line'' test, EPA's task in
conducting modeling for developing our FIP is to conduct modeling in
accordance with the CAA and RHR using our best scientific and technical
judgment. We then consider the modeling results, along with the other
BART factors, in making the BART determinations. While it is
permissible to establish a ``bright line,'' we have not done so.
Furthermore, as we discuss in detail in section IV of this final notice
and elsewhere in response to comments, we disagree with commenter's
assertions that there are no significant differences between Wyoming's
results and EPA's results. We have addressed the issue of
perceptibility elsewhere in our response to comments.
Comment: We received comments that by the year 2022, EPA's plan and
Wyoming's plan achieve essentially identical results for visibility,
and therefore, the proposed FIP would have no net visibility benefit
over the SIP.
Response: We disagree. Our proposed FIP, by merit of requiring more
stringent controls than those proposed in the SIP for some sources
shown to cause or contribute to visibility impairment, results in
greater visibility benefit. Although, based on our revised analyses for
visibility impacts and costs of compliance and considering the five
BART factors, we have revised some of
[[Page 5110]]
our proposed control determinations, this assessment remains true for
today's final rule. In particular, our final rule results in greater
visibility improvement than the SIP for PacifiCorp Dave Johnston Unit 3
and Wyodak and Basin Electric Laramie River Units 1-3. The improvement
in visibility stemming from the FIP, as compared to the SIP, can easily
be discerned by reviewing relevant control options as found in Tables 2
through 17 of section III.A of this action.
Comment: On average, the 2000 baseline level for Class I areas in
Wyoming is 11 deciviews. The 2064 natural background goal is 6
deciviews. IMPROVE data suggests that there is not this amount of
nitrate improvement to be obtained. It appears EPA is trying to achieve
a greater reduction for nitrates than is required at this time to reach
the 2064 natural background goal. For Bridger, the total amount of
deciview reduction for controls (6.08) exceeds the entire deciview
reduction (all pollutants) from baseline to 2064. The value (6.08
deciviews) is also 10 fold higher than Wyoming's contribution to
nitrate levels (0.62 deciviews--see Table 23 of EPA's proposed
rulemaking) at the Class I area for the 2000-2004 baseline year. This
value was calculated by multiplying 6.2% times the Class I area's 2000
baseline deciview value of 11.1. The same discussion is valid for
Yellowstone as well, where the modeled nitrate reductions equal 2.27
deciviews and Wyoming's total reduction potential is only 0.82
deciviews.
Response: EPA disagrees with this comment. The commenter appears to
be referring to annual mean estimates of visibility impairment at Class
I areas, and comparing these estimates with the original CALPUFF
modeled visibility improvements in our 2012 proposal. The values
referred to in Table 23 of EPA's proposed rulemaking are mean estimates
for the 20% worst visibility days. The BART Guidelines recommend that
visibility impairment be evaluated for the 98th percentile contribution
for each BART source. It is likely that 98th percentile visibility
impacts will differ significantly from annual mean impacts, so it is
not possible to directly compare our modeled impacts on the 98th
percentile day to seasonal mean or the mean of the worst 20% days.
However, we also note that in the revised final modeling included in
this action, the CALPUFF modeled visibility improvements are less than
the values cited above by the commenter from the original proposal, and
the commenter's comparisons are no longer relevant.
Comment: The measured visibility impairment at IMPROVE stations
offers a more certain and reliable quantification of the actual cause
of visibility impairment than the CALPUFF model approved by the EPA for
BART visibility assessments. CALPUFF is an EPA-approved model for long-
range transport, as described in the EPA's ``Guideline on Air Quality
Models'' 40 CFR Part 51 Appendix W, but only for the modeling of PSD
increments. The treatment of chemical transformation, which is a
crucial aspect for any model that is used for visibility assessments,
is considered to be inadequate within CALPUFF. In fact, the lead
modelers at the EPA's Office of Air Quality Planning and Standards have
initiated a formal regulatory process to more fully evaluate (and very
possibly replace) CALPUFF as an EPA-preferred model for long-range
transport.
Response: EPA disagrees that the use of monitoring data from the
IMPROVE network would provide a more accurate assessment of the
predicted degree of visibility from the use of controls at a source
than does CALPUFF. The commenter has not explained how monitoring data
could be used to assess the actual current contributions to visibility
impairment, and in any case, models are needed to estimate the
potential future visibility impacts from the use of a range of controls
at a specific source. In recommending the use of CALPUFF for assessing
source specific visibility impacts, EPA recognized that the model had
certain limitations but concluded that ``[f]or purposes of the regional
haze rule's BART provisions . . . CALPUFF is sufficiently reliable to
inform the decision-making process.'' \80\ EPA accordingly
appropriately used CALPUFF in this action. We further note that the
requirements of 40 CFR 51.112 and 40 CFR part 51, Appendix W, Guideline
on Air Quality Models (GAQM) and the BART Guidelines which refers to
GAQM as the authority for using CALPUFF, provide the framework for
determining the appropriate model platforms and versions and inputs to
be used. The use of CALPUFF is subject to GAQM requirements in section
3.0(b), 4, and 6.2.1(e) which includes an approved modeling protocol to
use the current 5.8 version.\81\
---------------------------------------------------------------------------
\80\ 70 FR at 39123.
\81\ Assessment of the ``VISTAS'' Version of the CALPUFF
Modeling System, EPA-454/R-08-007, August 2008; also see CALPUFF
Model Change Bulletins B (MCB-B), MCB-C and MCB-D.
---------------------------------------------------------------------------
In promulgating the BART guidelines, EPA addressed concerns with
CALPUFF's treatment of chemical transformations by recommending that
states use the 98th percentile of modeled visibility impacts,\82\ an
approach that EPA followed here, to address the possibility that the
model could overestimate impacts. EPA's discussion of CALPUFF in this
2005 rulemaking addresses these issues at length.\83\
---------------------------------------------------------------------------
\82\ 70 FR at 39121
\83\ 70 FR at 39121-29124.
---------------------------------------------------------------------------
EPA's modeling in this action was consistent with the BART
Guidelines and Appendix W. As explained in more detail above, in
recommending the use of CALPUFF for assessing source specific
visibility impacts, EPA recognized that the model had certain
limitations but concluded that ``[f]or purposes of the regional haze
rule's BART provisions . . . CALPUFF is sufficiently reliable to inform
the decision-making process.'' \84\ To the extent that the comment
takes issue with the provisions in the BART Guidelines for use of
CALPUFF as described above, the legal deadline for challenging the use
of CALPUFF has passed. In addition we encourage the commenter to
provide input in the event that EPA develops any new future visibility
guidelines and predictive models.
---------------------------------------------------------------------------
\84\ 70 FR at 39123.
---------------------------------------------------------------------------
With respect to the comment on the IMPROVE data, we have addressed
this in the response to another comment.
Comment: Regional haze is affected by global geologic, atmospheric
and anthropogenic sources. None of the sources are controllable to the
extent of achieving ``natural visibility conditions'' at the targeted
time frame. The quantification of ``natural visibility'' at any
geographic point is irrational. Natural visibility is a temporal
quantity and therefore any quantified value is subjective and not
scientific. Regional haze is subject to global atmospheric conditions
which provide dilutive action to the identified sources of haze
(anthropogenic or otherwise). Atmospheric conditions are directly
related to the baseline eleven year solar cycle. To have any form of
validity, the collection period would necessarily encompass at least
one full solar cycle, arguably two full cycles. Furthermore, the
dilutive effects of atmospheric conditions (and therefore, the
quantification of visibility) are directly related to the known
periodic oceanic events commonly referred to as ``el Ni[ntilde]o'' and
``la Ni[ntilde]a''. These events have been monitored and quantified
since 1950 and occurrences are sub-categorized as weak, moderate and
strong. The periodicity of strong events
[[Page 5111]]
for both ``el Ni[ntilde]o'' and ``la Ni[ntilde]a'' is every 9-11 years.
The last strong ``el Ni[ntilde]o'' occurred in 1997. The last two
strong ``la Ni[ntilde]a'' events occurred in 2010 and 1999. The
baseline data collection for regional haze is ignorant of these
significant atmospheric events, which makes the data collection period
irrelevant and therefore the ``baseline visibility'' invalid.
Response: EPA disagrees with the characterizations in this comment.
EPA recognizes that a variety of global scale, natural emissions
sources affect natural visibility levels at Class I areas, and we
described methods used to assess natural haze levels.\85\ We disagree
that it is necessary to model visibility impairment for one or two full
solar cycles. The formation of fine particulate matter, and subsequent
impacts on regional haze, depend on variations in local meteorological
conditions. Variability in meteorological conditions is primarily
determined by seasonal weather conditions, and the modeling period of
calendar years 2001-2003 used in our analysis includes substantial
variability in weather conditions. While phenomena such as el
Ni[ntilde]o and la Ni[ntilde]a can affect the frequency of extreme
events, our modeling analysis is based on the 98th percentile
visibility impacts and is therefore designed to exclude extreme events.
El Ni[ntilde]o and la Ni[ntilde]a events may also affect annual total
precipitation, temperature and other meteorological parameters,
however, the commenter has not provided any evidence that the 98th
percentile visibility impacts would differ significantly during an el
Ni[ntilde]o and la Ni[ntilde]a year. We believe that it is sufficient
to model visibility impairment for a 3 year period. In the preamble to
the BART Guidelines, we discussed meteorological variability and
explained how use of the 98th percentile would minimize the likelihood
that the highest modeled visibility impacts would be caused by unusual
meteorological conditions. 70 FR 39121. As explained above, our use of
the 98th percentile is consistent with the BART Guidelines and in
recommending the use of CALPUFF for assessing source specific
visibility impacts, EPA recognized that the model had certain
limitations but concluded that ``[f]or purposes of the regional haze
rule's BART provisions . . . CALPUFF is sufficiently reliable to inform
the decision-making process.'' \86\ Thus to the extent that the comment
suggests that the BART Guidelines should have used a different
percentile to account for solar variability in solar cycles, the legal
deadline for challenging the use of CALPUFF has passed. In addition we
encourage the commenter to provide input in the event that EPA develops
any new future visibility guidelines and predictive models.
---------------------------------------------------------------------------
\85\ ``Guidance for Estimating Natural Visibility Conditions
under the Regional Haze Rule'' Document No. EPA-R09-OAR-2012-0345-
0003-B9, U.S. Environmental Protection Agency, September, 2003.
\86\ 70 FR at 39123.
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2. EPA Modeling
a. Comments on EPA Modeling
Comment: Several commenters have argued that EPA should have used
updated models and procedures for its revised modeling. In addition,
several commenters have argued that the State's Protocol was overly
conservative in its treatment of background ammonia concentrations, and
that monitoring data show that background ammonia levels are
significantly lower than the 2 ppb concentration specified in the
Protocol. Commenters in particular directed EPA's attention to ambient
monitoring data for ammonia and particulate ammonium at a monitoring
site in Boulder in western Wyoming and at several Class I areas.
Ambient monitoring at the Boulder site was performed from 2006 to 2011
and these data were recently published by Li et al.,\87\ while the
monitoring data at the Class I areas for an 8 month period from April
2011 to January 2012 and were presented at a conference in 2012.\88\
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\87\ Li, Y., Schwandner, F.M., Sewell, H.J., Zivkovich, A.,
Tigges, M., Raja, S., Holcomb, S., Molenar, J.V., Sherman, L.,
Archuleta, C., Lee, T., Collett Jr., J.L., Observations of ammonia,
nitric acid, and fine particles in a rural gas production region,
Atmospheric Environment (2013), doi: 10.1016/j.atmosenv.2013.10.007.
\88\ Chen et al., A Pilot Monitoring Study of Atmospheric NHx at
Selected IMPROVE sites AWMA Aerosol and Atmospheric Optics,
Visibility & Air Pollution Conference, September 24-28, 2012,
Whitefish, MT.
---------------------------------------------------------------------------
Response: We agree with the comments that we should perform new
modeling using updated model versions and different background ammonia
concentrations. In this response we explain why we originally used the
same modeling approach used by Wyoming and why we have updated the
modeling for this action. In 2006, the State adopted its ``BART Air
Modeling Protocol'' (Protocol) \89\ that specified the approach for
using the CALPUFF modeling system to evaluate BART visibility impacts,
and the State and several BART sources performed modeling studies that
were consistent with that protocol. For our original proposal in 2012,
EPA performed additional modeling using the State's Protocol to
evaluate a limited number of emissions scenarios that the State had not
evaluated in its modeling. EPA recognized that there had been updates
to CALPUFF modeling guidance and model versions after 2006 when the
State adopted the Protocol, however, in our original proposal in 2012,
which included a limited, gap-filling analysis, we proposed that it was
preferable to maintain consistency with the modeling approach that the
State had adopted in its Protocol. In our re-proposal on June 10, 2013,
EPA recognized that some of the options used from the State's Protocol
were inconsistent with BART Guidelines, such as the approach for
determining baseline emissions. As a result, for the re-proposal EPA
performed new modeling using updated emissions data for the baseline
period and for all emissions control technologies, however, EPA
continued to use the State's Protocol for EPA's re-proposed modeling
analysis.
---------------------------------------------------------------------------
\89\ Wyoming's ``BART Air Modeling Protocol'' (Protocol) is
included in the docket in the State's Technical Support Document.
---------------------------------------------------------------------------
After evaluating comments on the re-proposal, EPA determined that
it was necessary to remodel all of the baseline and control technology
scenarios using different background ammonia concentrations for the
BART sources that we reconsidered for this action, including Naughton,
Jim Bridger, Laramie River, Dave Johnston and Wyodak. Because this
approach represents a significant change from State's original
Protocol, we believed that it was appropriate to develop a new modeling
protocol that also adopts the current model version approved for
regulatory use, CALPUFF version 5.8, and current regulatory default
options. In making this decision, we considered the merits of
continuing to use the State's original protocol versus the benefits of
using the updated CALPUFF model that became available after the State's
Protocol was adopted, and different background ammonia concentrations
based in part on data that have also become available since then, and
we concluded that it was necessary to adopt an updated Protocol \90\ to
respond fully to a number of issues raised by various commenters. The
new EPA Protocol for modeling of Wyoming BART uses the same CALPUFF
model version 5.8 as did the protocol that we previously adopted for
modeling BART sources visibility impacts in Montana.\91\
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\90\ Air Quality Modeling Protocol: Wyoming Regional Haze
Federal Implementation Plan, U.S. EPA, January, 2014.
\91\ Modeling Protocol: Montana Regional Haze Federal
Implementation Plan (FIP) Support, prepared for EPA Region 8 by
Alpine Geophysics, LLC, November 21, 2011.
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[[Page 5112]]
EPA evaluated the comments and the ambient ammonia monitoring data
submitted by commenters. EPA understands that there is no single
accepted method for estimating the background concentration of ammonia,
and that any method will have advantages and disadvantages. The lack of
consensus on a method was a factor in EPA's decision to set aside the 2
ppb concentration value specified in the State's Protocol and instead
to rely in part on the default values in Interagency Workgroup on Air
Quality Modeling (IWAQM) Phase 2 report \92\ and in part on monitoring
data. Specifically, for BART sources in western Wyoming we performed
two modeling runs, one relying on an IWAQM default value and the other
relying only on monitoring data. As presented below, EPA's two sets of
modeling results for this BART source support our final BART
determinations, as they both show similar visibility benefits. As
explained below, we relied only on an IWAQM default value for BART
sources in eastern Wyoming.
---------------------------------------------------------------------------
\92\ Interagency Workgroup On Air Quality Modeling (IWAQM) Phase
2 Summary Report And Recommendations For Modeling Long Range
Transport Impacts (EPA-454/R-98-019), EPA OAQPS, December 1998,
https://www.epa.gov/scram001/7thconf/calpuff/phase2.pdf.
---------------------------------------------------------------------------
The 1998 IWAQM report is the only guidance available for choosing
ammonia background concentrations. The IWAQM Phase 2 report relied on a
1992 review of ambient monitoring data for ammonia by Langford et
al.\93\ and explains that: ``. . . the formation of particulate nitrate
is dependent on the ambient concentration of ammonia, which
preferentially reacts with sulfate. The ambient ammonia concentration
is an input to the model. Accurate specification of this parameter is
critical to the accurate estimation of particulate nitrate
concentrations. Based on a review of available data, Langford et al.
suggest that typical (within a factor of 2) background values of
ammonia are: 10 ppb for grasslands, 0.5 ppb for forest, and 1 ppb for
arid lands at 20 degrees Celsius. Langford et al. (1992) provide strong
evidence that background levels of ammonia show strong dependence with
ambient temperature (variations of a factor of 3 or 4) and a strong
dependence on the soil pH. However, given all the uncertainties in
ammonia data, IWAQM recommends use of the background levels provided
above, unless specific data are available for the modeling domain that
would discredit the values cited. It should be noted, however, that in
areas where there are high ambient levels of sulfate, values such as 10
ppb might overestimate the formation of particulate nitrate from a
given source, for these polluted conditions. Furthermore, areas in the
vicinity of strong point sources of ammonia, such as feed lots or other
agricultural areas may experience locally high levels of background
ammonia.'' \94\
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\93\ Langford, A.O., F.C. Fehsenfeld, J. Zachariassen, and D.S.
Schimel (1992), Gaseous ammonia fluxes and background concentrations
in terrestrial ecosystems of the United States, Global
Biogeochemical Cycles, 6, 459-483.
\94\ Interagency Workgroup On Air Quality Modeling (IWAQM) Phase
2 Summary Report And Recommendations For Modeling Long Range
Transport Impacts, EPA-454/R-98-019, (December 1998) pages 14-15.
---------------------------------------------------------------------------
The IWAQM Phase 2 report also states that ``[i]n a refined
analysis, ``the background concentrations of ozone and ammonia are
allowed to vary in time and space.'' \95\ In summary, given numerous
uncertainties in ammonia data, the IWAQM Phase 2 report recommends use
of the background values it provides for different land use categories,
unless specific data is available in the modeling domain as a more
accurate substitute for its recommended default values, and allows for
the consideration of background ammonia concentrations that vary
seasonally or spatially.
---------------------------------------------------------------------------
\95\ IWAQM, Ibid., page 6.
---------------------------------------------------------------------------
EPA has reviewed monitoring data for ammonia and ammonium that have
been collected at one site in western Wyoming since 2006.\96\ We have
determined that the monitoring data from this site are the most
representative monitoring data available for characterizing ammonia and
ammonium background levels in the modeling domains used for western
Wyoming as explained in detail below. Based on this analysis, EPA has
concluded that the constant 2 ppb background concentration used by the
State is substantially higher than the observed combined ammonia and
particulate ammonium concentrations at this monitoring site in western
Wyoming, especially during the winter season when the observed sum of
ammonia and particulate ammonium concentration were typically much
lower than 2 ppb.\97\ Therefore, for two BART sources in western
Wyoming (PacifiCorp's Naughton and Jim Bridger) in one of our modeling
runs we modeled using monthly varying ammonia background concentrations
based on the combined observed concentration of ammonia and particulate
ammonium at this monitoring site in western Wyoming, as described in
the EPA Protocol.\98\ In a second modeling run for these two BART
sources, we modeled using the default IWAQM ammonia concentration of
0.5 ppb for forested areas. Although western Wyoming includes a mixture
of arid grasslands and forested areas, we used the IWAQM default value
of 0.5 ppb for forested areas because the Class I areas in the modeling
domain are primarily forested, and because the monitoring data more
nearly matched the IWAQM recommendation for forests than the default
for the other land types.
---------------------------------------------------------------------------
\96\ Li, Y., Schwandner, F.M., Sewell, H.J., Zivkovich, A.,
Tigges, M., Raja, S., Holcomb, S., Molenar, J.V., Sherman, L.,
Archuleta, C., Lee, T., Collett Jr., J.L., Observations of ammonia,
nitric acid, and fine particles in a rural gas production region,
Atmospheric Environment (2013), doi: 10.1016/j.atmosenv.2013.10.007.
\97\ Li et al. U.S. EPA, December, 2013.
\98\ Air Quality Modeling Protocol: Wyoming Regional Haze
Federal Implementation Plan.
---------------------------------------------------------------------------
When Wyoming adopted its Protocol in 2006, the State explained
that: ``A constant background ammonia concentration of 2.0 ppb is
specified. This value is based upon monitoring data from nearby states
and IWAQM guidance. Experience suggests that 2.0 ppb is conservative in
that it is unlikely to significantly limit nitrate formation in the
model computations.'' \99\
---------------------------------------------------------------------------
\99\ Wyoming Protocol, p. 12.
---------------------------------------------------------------------------
The Wyoming Protocol specified a constant 2 ppb background ammonia
concentration, but the Protocol (addressing source owners performing
their own BART analyses) states that: ``[i]f you believe that ammonia
limiting is appropriate for a specific BART analysis, justification
should be discussed with the Division prior to its use.'' \100\ The
Wyoming Protocol in the text quoted here refers to a method for
correcting CALPUFF for ammonia limiting conditions, which indicates
that the State recognized the possibility that its protocol could be
overly conservative in its treatment of ammonia. Therefore, we believe
it is appropriate and consistent with the IWAQM Phase 2 report and the
intention of the State's Protocol to model a BART source in western
Wyoming using both the newly available monitoring data, and the default
concentration recommended in the IWAQM Phase 2 report, to represent
background ammonia concentrations more accurately than would be the
case if we retained the 2 ppb value specified in the State Protocol.
---------------------------------------------------------------------------
\100\ Wyoming Protocol, p. 15.
---------------------------------------------------------------------------
We describe here in more detail the ambient monitoring data from
the site in western Wyoming and our use of those
[[Page 5113]]
data. Li et al (2013) \101\ report on an analysis of ambient monitoring
data conducted from 2006 to 2011 at the Pinedale site in western
Wyoming in an area with significant oil and gas production. The
monitoring site included measurements of gaseous ammonia
(NH3) and particulate ammonium (NH4) and a
complete set of acidic species including gaseous nitric acid and
particulate nitrate and sulfate. The complete set of measurements makes
it possible to determine the total ammonia and ammonium concentration
(NHX=NH3+NH4) and to determine if
ammonium nitrate formation is limited by the availability of excess
NH3. Li et al found significant seasonal variability in
NH3 and NH4 concentrations at the site and
concluded that excess nitric acid was present in winter, while
NH3 concentrations were close to zero in winter, indicating
that formation of ammonium nitrate was limited by the availability of
ammonia at this site in winter.\102\ Because ammonia at this monitoring
site may have been affected by nearby sources of sulfuric acid and
nitric acid, which would deplete the gaseous ammonia concentration
locally, we used the combined gaseous and particulate measurement of
NHX to estimate monthly average background ammonia
concentrations, with a low concentration in January of 0.36 ppb and a
peak concentration in 1.12 ppb in August.\103\ The monitor is located
in an area that includes nearby sources of ammonia emissions from
livestock and other anthropogenic sources, including a nearby area of
oil and gas production activity, which could result in locally elevated
ammonia compared to the area more immediate to the BART source and to
the nearest Class I areas. Moreover, some of the particulate ammonium
observed at the site was irreversibly bound with sulfate and may have
had a non-local origin due to long range transport of ammonium sulfate.
These factors mean that this estimate of local background may tend to
overestimate the regional background ammonia concentration and thus
also overestimate the visibility benefit due to NOX
reductions at sources. There may be other unknown factors also working
in the same direction or in the other direction. For example,
monitoring methods for ammonia and quality systems for characterizing
monitoring accuracy have not been standardized to the extent that
methods for other ambient compounds have been, resulting in uncertainty
as to whether there is bias in the measurements.
---------------------------------------------------------------------------
\101\ Li, Y., Schwandner, F.M., Sewell, H.J., Zivkovich, A.,
Tigges, M., Raja, S., Holcomb, S., Molenar, J.V., Sherman, L.,
Archuleta, C., Lee, T., Collett Jr., J.L., Observations of ammonia,
nitric acid, and fine particles in a rural gas production region,
Atmospheric Environment (2013), doi: 10.1016/j.atmosenv.2013.10.007.
\102\ Li et al., Ibid.
\103\ Air Quality Modeling Protocol: Wyoming Regional Haze
Federal Implementation Plan,U.S. EPA, December, 2013, page 18, Table
7.
---------------------------------------------------------------------------
As discussed above, we also modeled the PacifiCorp Naughton and Jim
Bridger BART sources in western Wyoming using a constant background
ammonia concentration of 0.5 ppb, which is the IWAQM Phase 2 report
default recommendation for forested areas. Model results using either
approach to determine an ammonia background concentration support our
final BART determinations, as they both show similar visibility
benefits.
We also remodeled the BART sources in eastern Wyoming including
Wyodak, Dave Johnston and Laramie River. The Class I areas most
impacted by these BART sources are Badlands and Wind Cave National
Parks in western South Dakota. The closest long-term ammonia monitoring
site to these Class I areas is at site at Beulah, North Dakota operated
by the State of North Dakota. This site is about 280 miles from
Badlands National Park and about 300 miles away from Wind Cave NP. The
area around Beaulah site includes a mix of agricultural lands and
grassland. Measured monthly average gaseous ammonia concentrations at
the Beulah site in central North Dakota vary from about 1 to 2 ppb
throughout the year, with the lowest values in fall and winter.\104\
Additionally, combined ammonia and particulate ammonium measurements
have been reported at Wind Cave National Park for an 8 month period by
Chen et al.\105\ This study measured NHX daily average
concentrations in the range of about 0.05 to 4 ppb, with an annual
average concentration of 0.75 ppb. We considered these monitoring data
sufficient to put into serious doubt the 2 ppb concentration specified
in the State's Protocol, but insufficient to support either a single or
an alternative modeling run based on monitoring data. Therefore, we
chose to rely on the IWAQM Phase 2 report for a single set of modeling
runs for the BART sources in eastern Wyoming. The area around Wind Cave
National Park includes forested areas, including Black Hills National
Forest, while the area around Badlands National Park includes a mix of
arid and grass lands. While there is uncertainty in the appropriate
background ammonia level in this region, we used the IWAQM Phase 2
report recommended value of 1 ppb for arid lands because it falls
within the range of the limited monitoring data available in nearby
regions and because it is represents an intermediate level for the
different land use types within the region.
---------------------------------------------------------------------------
\104\ Protocol for BART-Related Visibility Impairment Modeling
Analyses in North Dakota, November, 2005, North Dakota Department of
Health, Division of Air Quality, 1200 Missouri Avenue, Bismarck, ND
58506. Page 33.
\105\ Chen et al., A Pilot Monitoring Study of Atmospheric
NHX at Selected IMPROVE sites AWMA Aerosol and
Atmospheric Optics, Visibility & Air Pollution Conference, September
24-28, 2012, Whitefish, MT.
---------------------------------------------------------------------------
For both the eastern and western Wyoming modeling domains and runs,
we corrected for ammonia limiting conditions. The correction for
ammonia limiting conditions is a post-processing step in POSTUTIL, one
component of the CALPUFF modeling system. Because CALPUFF simulates
each BART unit individually, the background ammonia concentration is
assumed by the model to be fully available to react with emissions from
each unit. In reality, the total emissions from the combined units
compete for the available ammonia. Also, because CALPUFF simulates
multiple parcels of air originating at each unit, there is the
possibility that different parcels can overlap at a Class I area. The
ammonia limiting correction in POSTUTIL is designed to repartition the
available ammonia to react with emissions from all of the units and
overlapping air parcels, thereby avoiding double counting of the
background ammonia. We used the same ammonia limiting correction in our
modeling for Montana BART \106\ sources, and this is a standard
configuration in the CALPUFF modeling system.
---------------------------------------------------------------------------
\106\ Modeling Protocol: Montana Regional Haze Federal
Implementation Plan (FIP) Support, prepared for EPA Region 8 by
Alpine Geophysics, LLC, November 21, 2011.
---------------------------------------------------------------------------
In summary, we concluded that it was more reasonable to model
visibility impacts in western Wyoming using both the default IWAQM
Phase 2 report recommendation for forested areas and using a seasonally
varying NH3 concentration in western Wyoming that was based
on long term monitoring of NH3 and NH4 from one
site, than to use the 2 ppb concentration specified in the State's
Protocol. We found that the visibility impacts predicted for the
various control levels at the PacifiCorp Naughton and Jim Bridger BART
sources were very similar with these two approaches and that either set
of results supports the same BART determination for these sources.
Therefore, we did not have to make a
[[Page 5114]]
determination that one approach was superior to the other, and we have
not done so. We also determined that it was appropriate to use the
default IWAQM Phase 2 report recommendation of 1 ppb for eastern
Wyoming.
Comment: A commenter believes that the improvements from the
addition of SCR technology are based on highly conservative models
which overestimate the deciview reduction as compared to actual
monitored data collected at the IMPROVE stations. Subsequently, the
improvement in visibility provided by SCR is not supported by the
escalated costs of $600 million above the cost to install Wyoming's
proposed control technologies.
Response: EPA disagrees with this comment to the extent that it
takes issue with EPA's modeling. As discussed in response to other
commenters, EPA recognized that the State's original modeling protocol
specified a fixed value of 2 ppb for background ammonia. EPA has
performed new modeling using lower background concentrations and using
a correction for ammonia limiting conditions when modeling multiple
units from a single BART source.
EPA also used the most current regulatory approved versions of the
models in the updated modeling. EPA has recognized that the CALPUFF
model can be conservative in estimating visibility impairment, and
therefore, EPA has used the 98th percentile model results instead of
the maximum modeled visibility impairment to address the possibility of
model overpredictions. In recommending the use of CALPUFF for assessing
source specific visibility impacts, EPA recognized that the model had
certain limitations but concluded that ``[f]or purposes of the RHR's
BART provisions, CALPUFF is sufficiently reliable to inform the
decision making process, e.g., see 77 FR 39123.\107\ As discussed
above, to the extent that the comment takes issue with the use of the
98th percentile, the legal deadline for challenging the use of CALPUFF
has passed, but we encourage the commenter to provide input in the
event that EPA develops any new future visibility guidelines and
predictive models.
---------------------------------------------------------------------------
\107\ 77 FR 39123: ``Because of the scale of the predicted
impacts from these sources, CALPUFF is an appropriate or a
reasonable application to determine whether such a facility can
reasonably be anticipated to cause or contribute to any impairment
of visibility. In other words, to find that a source with a
predicted maximum impact greater than 2 or 3 deciviews meets the
contribution threshold adopted by the States does not require the
degree of certainty in the results of the model that might be
required for other regulatory purposes. In the unlikely case that a
State were to find that a 750 MW power plant's predicted
contribution to visibility impairment is within a very narrow range
between exemption from or being subject to BART, the State can work
with EPA and the FLM to evaluate the CALPUFF results in combination
with information derived from other appropriate techniques for
estimating visibility impacts to inform the BART applicability
determination. Similarly for other types of BART eligible sources,
States can work with the EPA and FLM to determine appropriate
methods for assessing a single source's impacts on visibility.''
---------------------------------------------------------------------------
Comment: The commenter states that EPA made five errors in its
visibility modeling, including (1) given the general inaccuracy in
CALPUFF unit-specific modeling, not allowing Wyoming the deference
accorded it under the CAA; (2) relying upon an outdated CALPUFF method
of visibility modeling, contrary to EPA precedent; (3) violating the
applicable modeling guidance, Appendix W, by not using the ``best''
science; (4) violating the Data Quality Act by not using the ``best''
science; and (5) failing to recognize the gross overestimations and
internal inconsistencies in EPA's modeling approach.
Response: EPA disagrees with this comment. In response to item (1):
In promulgating the BART guidelines we made the decision in the final
BART Guideline to recommend that the model be used to estimate the 98th
percentile visibility impairment rather than the highest daily impact
value as proposed. We made the decision because ``there are other
features of our recommended modeling approach that are likely to
overstate the actual visibility effects of an individual source. Most
important, the simplified chemistry in the model tends to magnify the
actual visibility effects of that source. Because of these features and
the uncertainties associated with the model, we believe it is
appropriate to use the 98th percentile, a more robust approach that
does not give undue weight to the extreme tail of the distribution.''
77 FR 39121. In regard to deference to the state, as discussed in more
detail elsewhere in this document, Congress crafted the CAA to provide
for states to take the lead for implementing plans, but balanced that
decision by requiring EPA to approve the plans or prescribe a federal
plan should the state plan be inadequate to meet CAA and regulatory
requirements. Our action today is consistent with the statute and
regulations. In response to item (2): We initially relied on the
State's modeling Protocol, adopted in 2006, that specified model
versions available at that time, but that have since been updated. In
our original proposal we performed limited gap filling modeling that
was consistent with the State's Protocol and that used the same model
versions as the State. In this final action, as presented in more
detail in the Protocol in the docket, due to a number of other changes
in the protocol, we also updated the protocol to use the current
regulatory version of the CALPUFF modeling system. In response to items
(3) and (4): In recommending the use of CALPUFF for assessing source
specific visibility impacts, EPA recognized that the model had certain
limitations but concluded that ``[f]or purposes of the regional haze
rule's BART provisions . . . CALPUFF is sufficiently reliable to inform
the decision-making process.'' \108\ EPA accordingly appropriately used
CALPUFF in this action. EPA recognized that there were uncertainties in
the science of the CALPUFF modeling system, and therefore used the less
conservative 98th percentile value to model results to address the
possibility that the model was overly conservative. We address concerns
about the Data Quality Act (also referred to as the Information Quality
Act), elsewhere in this document. In response to item (5): EPA
recognized that the State's original Protocol was inconsistent with the
IWAQM report and monitoring data because of the use of a constant 2 ppb
ammonia concentration, and our modeling in this action relied on
ambient monitoring data and the default values consistent with IWAQM
Phase 2 report, to specify two alternatives for more realistic
background ammonia concentrations in western Wyoming. We also reduced
the background ammonia concentration from 2 to 1 ppb in eastern
Wyoming, as discussed previously. A seasonal ammonia concentration was
not adopted due to the lack of high quality monitoring data in eastern
Wyoming; however, as discussed previously, the 1 ppb background
estimate is consistent with IWAQM Phase 2 report. As discussed
elsewhere, we also used the ammonia limiting correction for modeling
multiple units from a single BART source to address concerns with the
model being overly conservative.
---------------------------------------------------------------------------
\108\ 70 FR at 39123.
---------------------------------------------------------------------------
Comment: Contrary to its own guidance, EPA failed to use the most
realistic model. 40 CFR part 51, Appendix W, EPA's modeling guidance,
demands that the ``best'' model should always be used. EPA failed to
use the ``best'' model in Wyoming, which is CALPUFF 6.4. Therefore, EPA
failed to follow Appendix W's requirements.
Response: We disagree with this comment. As explained above, EPA
followed the RHR. Specifically, in recommending the use of CALPUFF for
assessing source specific visibility impacts, EPA recognized that the
model had certain limitations but concluded
[[Page 5115]]
that ``[f]or purposes of the regional haze rule's BART provisions . . .
CALPUFF is sufficiently reliable to inform the decision-making
process.'' \109\ EPA accordingly appropriately used CALPUFF in this
action. The use of CALPUFF is subject to GAQM requirements in section
3.0(b), 4, and 6.2.1(e) which includes an approved protocol to use the
current 5.8 version, which is the version we used for EPA's final
modeling analysis. We did not use CALPUFF Version 6.4 because this
version of the model has not been approved by EPA for regulatory use.
---------------------------------------------------------------------------
\109\ 70 FR at 39123.
---------------------------------------------------------------------------
We made the decision in the final BART Guidelines to use less than
the highest daily impact value for assessment of visibility impacts. We
made this decision in response to comments we received expressing
concern that the chemistry modules in the CALPUFF model are less
advanced and that use of the 1st High was conservative and the
knowledge that CALPUFF's simplified chemistry could lead to model
overpredictions and thus be conservative. We decided in the BART
Guideline to use the 98 percentile for CALPUFF based modeling results.
We also received comments opposed to using the day with the worst
meteorology, but the primary reason we changed to using a less
stringent metric than the day with the highest visibility impact was
because of concerns about overestimations in CALPUFF's simplified
chemistry. As a result, we determined that it was appropriate to use
the 98th percentile or 8th High value when modeling all days of the
year instead of the 1st High value, also described as the Highest Daily
impact level for each year modeled: ``Most important, the simplified
chemistry in the model tends to magnify the actual visibility effects
of that source. Because of these features and the uncertainty
associated with the model, we believe it is appropriate to use the 98th
percentile--a more robust approach that does not give undue weight to
the extreme tail of the distribution.'' \110\
Comment: EPA's modeling for its regional haze FIP action was
inadequate and incomplete. (EPA failed to re-run WRAP regional modeling
due to ``time and resource constraints''). Therefore, EPA's regional
haze FIP action violates the ``Guideline on Air Quality Models,'' 40
CFR part 51 Appendix W, the Information Quality Act and the
implementing guidelines issued, respectively, by the U.S. Office of
Management and Budget (OMB) and the EPA which require information
disseminated by EPA to be accurate, complete, reliable and unbiased.
The Information Quality Act and EPA's ``Information Quality
Guidelines'' place a heightened standard on ``influential''
information, including scientific information regarding health, safety,
or environmental risk assessments. EPA's inaccurate and incomplete
visibility modeling is by definition ``influential,'' because EPA could
reasonably determine that dissemination of the information will have or
does have a clear and substantial impact on important public policies
or important private sector decisions, such as the BART NOX
determinations in EPA's regional haze FIP.
Therefore, this ``influential'' information must be based on best
available science and data and supporting studies must be conducted in
accordance with sound objective scientific practices and methods. EPA's
Guidelines implementing the Information Quality Act expressly
contemplate the correction of information disseminated by EPA that
falls short of the ``basic standard of quality, including objectivity,
utility, and integrity,'' established by either EPA's own Guidelines or
those issued by OMB.
The commenter seeks correction to a number of errors and omissions
in EPA's regional haze FIP with regard to CALPUFF modeling and EPA's
failure to re-run the WRAP model. The commenter requests that EPA
withdraw its regional haze FIP until these issues are resolved.
Response: As EPA explained in our Information Quality Guidelines,
we believe ``that the thorough consideration provided by the public
comment process serves the purposes of the Guidelines, provides an
opportunity for correction of any information that does not comply with
the Guidelines, and does not duplicate or interfere with the orderly
conduct of the action.'' \111\ Therefore, we are responding to the
modeling comments and related comments regarding EPA's Guidelines and
the Information Quality Act in this document.
---------------------------------------------------------------------------
\111\ Guidelines for Ensuring and Maximizing the Quality,
Objectivity, Utility, and Integrity of Information Disseminated by
the Environmental Protection Agency, EPA/260R-02-008 October 2002,
U.S. Environmental Protection Agency Office of Environmental
Information (2810) 1200 Pennsylvania Avenue NW., Washington, DC
20460.
---------------------------------------------------------------------------
WRAP performed regional photochemical modeling using both the
Community Multi-Scale Air Quality modeling system (CMAQ) and
Comprehensive Air Quality Model (CAMx) air quality models to evaluate
progress toward attaining visibility goals using all projected emission
changes from all source categories throughout the United States. WRAP
did not perform regional photochemical modeling to evaluate the
visibility impacts of individual BART sources. While WRAP did make
assumptions regarding the level of emissions control that would be
adopted by BART sources as part of its analyses, no state or EPA region
has re-run the WRAP's regional photochemical models to assess
individual BART source contributions to visibility impairment. Instead,
the BART sources, the states, and EPA have used the CALPUFF model to
evaluate contributions to visibility impairment from individual BART
sources. This approach is consistent with the BART Guidelines that
recommend that the CALPUFF model should be used to evaluate visibility
impairment from individual BART sources. Additionally, while EPA
supported development of WRAP CMAQ modeling in order to assist states
in developing their RPGs and determining the cumulative benefit of an
overall control strategy vis-[agrave]-vis the URP on the 20% worst
days, our use of CALPUFF for evaluating visibility improvement from a
single BART source is consistent with the BART Guidelines and also
consistent with modeling performed by other states and EPA regional
offices for individual BART sources.
We have responded to comments related to errors and omissions in
the CALPUFF modeling in separate response to comments.
Comment: The commenter states that the revised EPA modeling, which
used new information on emissions rates, did not significantly change
the results identified in Wyoming's BART analyses. The commenter also
states that there are small differences between EPA's and Wyoming's
analyses which do not justify EPA rejecting Wyoming's BART
determinations.
Response: We disagree that in all cases there are only small
differences in EPA revised modeling and the State's modeling.
Importantly, as described elsewhere in this document and in the docket
for this action, EPA revised and corrected various inputs to the BART
factors so that the analyses are consistent with the RHR and statutory
requirements. While the difference at the most impacted Class I area
from individual sources or units is some cases can be characterized as
small, the cumulative differences from many small improvements can be
significant. Whether such differences are significant will depend on
the overall consideration of the BART factors. Because of the flaws in
Wyoming's
[[Page 5116]]
visibility and cost analyses for many of its BART sources, EPA could
not be confident that Wyoming's BART determinations were reasonable
without undertaking an appropriate analysis of the statutory factors.
Comment: The commenter states that Wyoming provided the required
modeled visibility improvement information for SCR, and quotes from the
State's analysis: ``Post-Control Scenario B is directly comparable to
Post-Control Scenario A as the only difference is directly attributable
to the installation of SCR.'' The commenter then concludes EPA did not
lack the required information to evaluate visibility improvements.
Response: We have addressed this comment in a previous response,
citing the requirement in the BART Guidelines that visibility must be
assessed relative to the pre-control scenario (and not just incremental
to other control scenarios). Moreover, there remain deficiencies, as
presented elsewhere in this document and docket, with the State's BART
modeling analyses that justify our rejection of the State's BART
determinations for PacifiCorp. Most notably, as discussed in separate
responses, the State did not assess the visibility improvement of SNCR
as required by the CAA and BART Guidelines.
Comment: An older version of the CALPUFF modeling suite was used by
EPA (CALPUFF model of March 2006 vintage and the CALPOST model of April
2006 vintage.) These older versions pre-date the latest Model Change
Bulletin (MCB-D) of June 23, 2007. Since the analysis for the five
Wyoming power plants was performed in February thru April 2012, we
question why the older version was used and not the current CALPUFF 5.8
version, which was approved as the guideline version in June of 2007.
We do not recommend use of the older versions of CALPUFF and CALPOST.
Response: As described in this action, our previous modeling
continued to use the State's Protocol, including the older model
versions, to maintain consistency with the State's modeling results.
However, in this final action, we adopted a new modeling protocol that
uses the current regulatory versions of the models, including the Model
Change Bulletin suggested by the commenter. We determined that it was
appropriate to adopt an updated modeling protocol because we made other
significant changes in the State's modeling approach, and because we
remodeled all emissions scenarios, there was no longer a need to use
older model versions for consistency of comparison of our limited gap
filling model results to the State's original modeling.
Comment: EPA should have used the most recent version of CALPUFF,
or at a minimum, should have used the version that EPA requires for
other regional haze SIPs. EPA has taken the position that CALPUFF
Version 5.8 must be used for regional haze modeling. 77 FR 42834,
42854. However, EPA's unit-specific CALPUFF modeling in Wyoming,
completed in April 2012, used CALPUFF Version 5.711a (originally
released in 2004). Version 5.711a is eight years old, and several
CALPUFF versions behind Version 5.8. While PacifiCorp believes the more
modern and realistic CALPUFF Version 6.42 should be used, at a minimum
EPA must abide by its own position and use Version 5.8 in evaluating
the Wyoming regional haze SIP, which it failed to do. According to
EPA's own statements, EPA's own modeling results should be discarded
because EPA used an improper ``alternative model'' in Wyoming.
EPA should have used the most recent version of CALPUFF (Version
6.42) in Wyoming because it produces more realistic and accurate
results. Version 6.42 contains needed refinements, such as a better
``chemistry'' module known as ISORROPIA (Version 2.1). CALPUFF Version
6.42 is more accurate because, as the FLMs have noted, Version 5.8 does
not have the required settings to perform the new Method 8 visibility
analysis. Additionally, CALPUFF Version 6.42 has been maintained by
TRC, Inc., a private contractor, and has had many bug fixes and
enhancements not included in CALPUFF Version 5.8. Most importantly, the
previous chemistry modules used in Version 5.8 (and in the 5.711a
Version EPA used here) also have been shown to overestimate nitrate
concentrations in Wyoming by a factor of 3-4 and substantial
improvements have been made to eliminate this over-prediction using the
ISORROPIA module.
Despite all these advancements in modeling and modeling science,
EPA conducted its modeling for its regional haze FIP in 2012 using the
same (now outdated) CALPUFF version that PacifiCorp and Wyoming used
five years ago, which has been shown to overestimate results by 300% to
400%. Rejecting Wyoming's modeling, and then using the same, outdated
modeling approach, is arbitrary and capricious.
Response: As described in previous responses, we previously used
the same modeling protocol adopted by the State for the purpose of our
limited, gap filling modeling, so that we would have a consistent basis
for comparison with the State's modeling. In this action we have
updated the protocol to use the current regulatory versions of the
models including CALPUFF version 5.8.
We did not use CALPUFF Version 6.42 because this version of the
model has not been approved by EPA for regulatory use. EPA relied on
version 5.8 of CALPUFF because it is EPA-approved version in accordance
with the Guideline on Air Quality Models (``GAQM'', 40 CFR 51, Appendix
W, section 6.2.1.e). EPA updated the specific version to be used for
regulatory purposes on June 29, 2007, including minor revisions as of
that date. The approved CALPUFF modeling system includes CALPUFF
version 5.8, level 070623, and CALMET version 5.8 level 070623. CALPUFF
version 5.8 has been thoroughly tested and evaluated, and has been
shown to perform consistently with the initial 2003 version in the
analytical situations for which CALPUFF has been approved. Any other
version, and especially one with such fundamental differences in its
handling of chemistry, would be considered an ``alternative model'',
subject to the provisions of GAQM section 3.2.2(b), requiring full
model documentation, peer-review, and performance evaluation. No such
information for the later CALPUFF versions that meet the requirements
of section 3.2.2(b) has been submitted to or approved by EPA.
Experience has shown that when the full evaluation procedure is not
followed, errors that are not immediately apparent can be introduced
along with new model features. For example, changes introduced to
CALMET to improve simulation of over-water convective mixing heights
caused their periodic collapse to zero, even over land, so that CALPUFF
concentration estimates were no longer reliable.\112\
---------------------------------------------------------------------------
\112\ ``CALPUFF Regulatory Update'', Roger W. Brode,
Presentation at Regional/State/Local Modelers Workshop, June 10-12,
2008; https://www.cleanairinfo.com/regionalstatelocalmodelingworkshop/archive/2008/agenda.htm.
---------------------------------------------------------------------------
The change from CALPUFF version 5.8 to CALPUFF 6.4 is not a simple
model update to address minor issues, but a significant change in the
model science that requires its own rulemaking with public notice and
comment before it can be relied on for regulatory purposes.
Furthermore, it should be noted that the U.S. Forest Service and
EPA review of CALPUFF version 6.4 results for a limited set of BART
applications showed that differences in its results from those of
version 5.8 are driven by two input assumptions not associated
[[Page 5117]]
with the chemistry changes in 6.4. Use of the so-called ``full''
ammonia limiting method and finer horizontal grid resolution are the
primary drivers in the predicted differences in modeled visibility
impacts between the model versions. These input assumptions have been
previously reviewed by EPA and the FLMs and have been rejected based on
lack of documentation, inadequate peer review, and lack of technical
justification and validation.
Comment: The commenter states that EPA treats the results from the
CALPUFF as being capable of accurately predicting visibility
improvements down to the tenths or hundredths of a deciview, but that
the model does not accurately predict visibility impacts at this level.
Response: As described in response to other comments, EPA
recognized that there is uncertainty in the CALPUFF results, and EPA
addressed this uncertainty by using the modeled 98th percentile
visibility impairment rather than the maximum visibility impairment.
EPA considers model changes on the order of tenths of a deciview to be
useful for informing the BART decision process, consistent with BART
modeling performed by other EPA regions and states.
Comment: PacifiCorp presented substantial information supporting
the need to use improved and updated versions of the models and
provided substantial information on the effects that the nitrogen
oxides to nitrogen dioxide conversion rate and background ammonia
concentrations have on modeled visibility impacts.
Response: We agree with the comment that the background ammonia
concentration has a significant effect on model predicted visibility
impacts. As described elsewhere in this action, we reviewed recent
ambient monitoring data for ammonia and particulate ammonium, and
concluded that the original background ammonia concentration of 2 ppb
was inconsistent with the IWAQM Phase 2 report and monitoring data for
estimating visibility impacts in Wyoming, especially in the western
portion of the State. In the modeling results included in this action,
we considered the default value of 0.5 ppb and also applied a
seasonally varying background ammonia concentration in western Wyoming
that was based on measurements from 2006 to 2011 of total ammonia and
particulate ammonium at Pinedale, Wyoming.\113\ We also reduced the
background ammonia concentration to 1 ppb in the eastern portion of the
State, and for both parts of the State we used an ammonia limiting
correction for modeling multiple units from a single BART source to
avoid double counting of the available ammonia. The use of more
realistic ammonia background concentrations, the ammonia limiting
correction, and the use of the 98th percentile modeled impact address
the concern that the CALPUFF model could overestimate visibility
impacts.
---------------------------------------------------------------------------
\113\ Li et al. 2013
---------------------------------------------------------------------------
Comment: One commenter stated that we underestimated the background
ammonia concentration in the CALPUFF modeling, and cited the IWAQM
Phase 2 recommendations for default ammonia concentrations for
grasslands, forest lands and arid lands, respectively, of 10, 0.5 and 1
ppb, at 20 degrees Celsius. The commenter stated that, because land use
type can vary across the large domains used in the CALPUFF modeling, it
would be appropriate to calculate a weighted average of the background
ammonia based on the fractional land use type in the model domain.
Response: We disagree with this comment. The IWAQM Phase 2 report
does not recommend calculating a weighted average of default ammonia
concentration based on regional variation in land use types. The
commenter provides no regulatory basis for use of a weighted average.
Comment: One commenter stated that the IWAQM recommended default
background ammonia recommendations do not specifically account for
strong point/area sources of ammonia, such as cattle feedlots, which
are also scattered throughout the modeling domain and which generally
add to the background ammonia levels. This commenter stated that some
areas of the modeling domain, namely northeastern Colorado, are
described as ``ammonia rich''. For BART source analyses in Colorado,
the recommended background ammonia value from the Colorado Department
of Public Health and Environment (CDPHE) is 44 ppb, based on
measurements conducted during the Northern Front Range Air Quality
Study (NFRAQS), and therefore the Wyoming DEQ/EPA background ammonia
concentration of 2 ppb might not carry sufficient ammonia for an
accurate modeling assessment of visibility impacts within certain
Colorado Class I areas.
Response: We disagree with the comment that large point/area
sources are not included in estimates of background ammonia
concentrations. While concentrations of ammonia of several hundred ppb
can be observed near a cattle feedlot, these concentrations are not
typical of regional background concentrations. Additionally, dispersion
and vertical mixing occur in plumes of air transported downwind of
large emissions sources, and the resulting dilution of ammonia results
in lower concentrations as the plume is transported downwind of the
source area. Therefore, ambient ammonia concentrations are generally
greatly reduced downwind from the source. Moreover, ammonia has a short
atmospheric lifetime of a few hours to a few days,\114\ and removal of
ammonia by deposition further reduces the concentration downwind of the
source area. Therefore, it would be inappropriate to estimate
background ammonia levels by measuring ammonia concentrations close to
a large ammonia emissions source. Background concentrations of air
pollutants are generally estimated using ambient monitoring data at
background sites that are specifically selected such that there is no
direct influence by large nearby point or areas sources.\115\
Therefore, background monitoring data do explicitly include the
contributions of emissions from large point and area sources by
providing a direct measurement of the ambient concentration after
transport, dilution and removal processes operate on the emissions from
the source.
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\114\ Langford et al.
\115\ For example, see EPA guidance documents that discuss
methods for estimating background NO2 concentrations: ``Additional
Clarification Regarding Applicability of Appendix W Modeling
Guidance for the 1-hour NO2 NAAQS''
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The commenter also cites modeling performed by the CDPHE and
ammonia measurements made during the NFRAQS studies. As discussed in
another response, CDPHE performed a CALPUFF model sensitivity study to
evaluate the effect of background ammonia on model predicted nitrate
concentrations, and found that the CALPUFF model was insensitive to
variations in background concentrations greater than 10 ppb and became
progressively more sensitive to background NH3 as it was reduced from
10 to 0 ppb.\116\ The NFRAQS study reported measured ammonia
concentrations in the Denver metropolitan area, and these measurements
are not representative of background ammonia concentrations in
[[Page 5118]]
rural and remote areas of central Colorado or western Wyoming.
---------------------------------------------------------------------------
\116\ Supplemental BART Analysis CALPUFF Protocol for Class I
Federal Area Visibility Improvement Modeling Analysis, DRAFT,
revised Aug 19, 2010, Colorado Department of Public Health and
Environment. (CDPHE) Air Pollution Control Division Technical
Services Program, 4300 Cherry Creek Drive South, Denver, Colorado
80246, pages 26-33.
---------------------------------------------------------------------------
Comment: The commenter states that Wyoming has conducted its
regional haze SIP based on the modeling protocols and versions
available at the time its regional haze SIP was completed. Because of
this, there are limitations associated with the results obtained.
However, in proposing its regional haze SIP, Wyoming has evaluated the
model output with an understanding of the model's limitations. Wyoming
then applied its judgment, as encouraged and required by EPA's
guidelines and the CAA, which helped to mitigate the issues associated
with models that over-predict the visibility improvement associated
with BART controls being added. In contrast, EPA gives no consideration
to the limitations of the models it uses. In the absence of using good
judgment to deal with over-predictive results, it is critical that EPA
use the most up-to-date and scientifically accurate models available.
We also received related comments that states have significant
modeling discretion to which EPA failed to grant the proper deference.
One commenter pointed out that the BART Guidelines recognize that
states can make judgments regarding the use of modeling results due to
the very real problems with CALPUFF, including its overestimation of
visibility improvement. As EPA itself has stated, Wyoming should be
free to make its own judgment about which modeling approaches are valid
and appropriate. 70 FR 39123. Another commenter pointed to the
statement that ``we must permit States to take into account the degree
of improvement in visibility that would result from imposition of BART
on each individual source when deciding on particular controls.'' 70 FR
39107, 39129. Another commenter stated that EPA failed to allow Wyoming
to account for CALPUFF's overestimation of NOX impacts, and
therefore, EPA is not affording Wyoming's BART decisions the proper
deference when it comes to the modeling and applying the modeling
results.
Response: As discussed elsewhere in this document in greater
detail, Congress crafted the CAA to provide for states to take the lead
for implementing plans, but balanced that decision by requiring EPA to
approve the plans or prescribe a federal plan should the state plan be
inadequate. Our action today is consistent with the statute. As also
discussed elsewhere in this document, we agree that there are
limitations in the original modeling performed by the state, and
therefore, it was necessary to perform new modeling using more
realistic background ammonia concentrations, default values, and
updated model versions to provide a sound basis for evaluating BART
source visibility impacts. Our revised modeling is consistent with the
BART Guidelines and with visibility modeling guidance in the IWAQM
Phase 2 report, and we believe that the revised modeling constitutes a
sound basis for evaluating visibility impacts of BART sources and in
fact is supportive of Wyoming's SIP with respect to sources where
ammonia background makes a significant differences.
Comment: The commenter states that EPA should have used the most
recent version of CALPUFF (Version 6.42) in Wyoming because it produces
more realistic and accurate results and because Version 5.8 does not
have the required settings to perform the new Method 8 visibility
analysis.
Response: As described in response to another comment, we used
CALPUFF version 5.8 because this is the approved regulatory version of
the model, while CALPUFF version 6.42 has not been approved. CALPUFF
version 5.8 does allow the option of using the Method 8 visibility
analysis, and as described in our modeling protocol, we used Method 8
for our analysis. The availability of Method 8 in CALPUFF version 5.8
was one of the reasons that we determined it was important to perform
new modeling using the current regulatory version of the model, rather
than continuing to rely on the original protocol adopted by the State
in 2006, as we had done in our previous proposal.
Comment: EPA used a different background ammonia number for
modeling than it requires of the states, and ignored current science on
background ammonia. Regional haze modeling, and the resulting predicted
visibility improvement, is greatly influenced by the background ammonia
number used in the model. EPA improperly used a constant 2 ppb
background ammonia number for the Wyoming BART modeling. EPA has not
provided any scientific proof showing the constant 2 ppb ammonia number
is appropriate for Wyoming. The 2 ppb ammonia value overestimates
visibility improvement, contrary to the approach used by Wyoming Land
Use, IWAQM Guidance, WRAP protocols, and elsewhere.
Commenter suggests that the WRAP recommended the use of 1 ppb of
ammonia year round for states in the region to account for seasonal
variability. EPA has required states to use 1 ppb of background ammonia
when conducting regional haze modeling. 76 FR 52434 (New Mexico
criticized for not using 1 ppb background ammonia). At a minimum EPA
should follow its own guidelines and use 1 ppb of background ammonia
when conducting CALPUFF unit-specific modeling.
However, the ``best'' science requires the use of ``variable
ammonia'' background numbers. IWAQM recommends ammonia background
numbers of 0.5 ppb for forest, 1 ppb for dry/arid lands, and 10 ppb for
agriculture/grassland. Given its geographic location and elevation
levels, Wyoming undergoes seasonal swings of dry-hot summers and snow
covered ground in the winter. Therefore, the use of a single ammonia
concentration for the entire year in a state where the land use and
land cover changes significantly between seasons results in
overestimation of visibility improvements. This is particularly true in
winter when agricultural activity is minimal and meteorological
conditions make visibility calculations particularly sensitive to
ambient ammonia concentrations. EPA has approved the use of variable
gaseous ammonia concentrations before, including the ``Addendum to
Modeling Protocol for the Proposed Desert Rock Generating Station'' and
should have used them when conducting the CALPUFF modeling for Wyoming.
Sensitivity tests on ambient ammonia concentrations were performed
by the CDPHE for an area in northwest Colorado. The analysis
demonstrated that visibility calculations performed at Mount Zirkel
Wilderness Area in northwest Colorado had limited impact when ambient
ammonia concentrations were reduced from 100 to 1 ppb, but there was a
significant reduction in visibility impacts when concentrations were
further reduced to 0.1 ppb.
Given the evidence presented above, the use of the monthly varying
ammonia would provide accurate estimates of visibility impacts from the
PacifiCorp regional haze units. EPA's failure to use variable
background ammonia in its modeling is arbitrary and capricious.
Response: We agree that the 2 ppb constant background ammonia
concentration is inconsistent with the IWAQM Phase 2 report default
values and monitored data. This value was adopted by the State in 2006
before more reliable ammonia and particulate ammonium measurements were
available in Wyoming. As described in this action, we modeled using
seasonally varying background ammonia concentrations in western Wyoming
based on 5 years of
[[Page 5119]]
monitoring data,\117\ and we also modeled using the IWAQM default value
of 0.5 ppb for forests. In eastern Wyoming we adopted a constant 1 ppb
ammonia concentration based on the IWAQM guidance. We used an ammonia
limiting correction for BART sources with multiple units throughout the
State. While robust, long term monitoring data of ammonia and
particulate ammonium are not available in eastern Wyoming, the BART
sources in eastern Wyoming, and the South Dakota Class I areas where
they contribute the greatest visibility impairment, are located closer
to areas of Nebraska and the Dakotas which have large agricultural
sources of ammonia emissions. Moreover, the IMPROVE monitoring at the
South Dakota Class I areas show much higher winter concentrations of
ammonium nitrate than do Class I areas in western Wyoming. Therefore,
we believe it is appropriate to adopt higher background ammonia
concentrations in eastern Wyoming than in western Wyoming, and we used
a constant 1 ppb ammonia concentration in eastern Wyoming, consistent
with the IWAQM guidance \118\ for arid lands and also consistent with
the WRAP Protocol.\119\
---------------------------------------------------------------------------
\117\ Li et al., 2013.
\118\ Interagency Workgroup On Air Quality Modeling (IWAQM)
Phase 2 Summary Report And Recommendations For Modeling Long Range
Transport Impacts (EPA-454/R-98-019), EPA OAQPS, December 1998.
\119\ Tonnesen, G., Wang, Z., Morris, R., Hoats, A., Jia, Y.,
Draft Final Modeling Protocol, CALMET/CALPUFF Protocol for BART
Exemption Screening Analysis for Class I Areas in the Western United
States, Submitted to the Western Regional Air Partnership, August
15, 2006.
---------------------------------------------------------------------------
Comment: EPA made a modeling error in Wyoming when it used CALPOST
version 5 with Method 6. FLMs recommended in 2000 the use of Method 6
to determine visibility impacts from BART eligible sources. However,
for any recent PSD application and BART modeling since 2010, EPA has
requested that Method 8 be used for determining impacts on visibility
at nearby Class I areas.
The previously preferred Method 6 simply computes background light
extinction using monthly average relative humidity adjustment factors
particular to each Class I area applied to background and modeled
sulfate and nitrate. Six years after the development of Method 6 in
1999, EPA released enhancements to the background light extinction
equations, which use the revised IMPROVE variable extinction efficiency
formulation. These enhancements take into account the fact that
sulfates, nitrates and organics and other types of particles have
different light extinction coefficients. Also, the background
concentrations at each Class I area have been updated by EPA to reflect
natural background visibility condition estimates for each Class I area
for each type of particle. Additionally, relative humidity adjustment
factors have been tailored separately for small particles, large
particles, and to account for sea salt background concentrations.
These new enhancements to the calculation method, called Method 8,
greatly improve the accuracy of the estimated visibility impact. Method
8 was added to CALPOST in 2008 and was adopted as the preferred option
for determining impacts on visibility by the FLMs in their ``Federal
Land Managers Air Quality Related Values Work Group Guidance Document''
in 2010 (FLAG 2010). The applicable background concentrations and
relative humidity adjustment factors using Method 8 for each Class I
area are identified in the FLAG 2010 document.
Despite the update to Method 8 in 2008 and the stated preference by
the FLMs in 2010 to use Method 8, EPA conducted the Wyoming BART
modeling in 2012 using the long outdated and scientifically inferior
Method 6. EPA's use of Method 6, and not Method 8, is arbitrary and
capricious.
Response: We agree that it is preferable to use Method 8 rather
than Method 6 for evaluating visibility impacts based on the
recommendation of the FLMs in FLAG 2010.\120\ The older CALPUFF version
5.711 that was adopted in the State's original modeling protocol in
2006 did not have the option of using Method 8. In our previous
modeling we adopted the State's original protocol to maintain a
consistent basis of comparison with the State's modeling results. In
this final action, we adopted an updated modeling protocol using the
current regulatory version of the model, which allows the use of Method
8, and we used Method 8 for the analysis of visibility impacts.
---------------------------------------------------------------------------
\120\ Federal Land Managers' Air Quality Related Values Work
Group (FLAG) Phase I Report--Revised (2010).
Natural Resource Report NPS/NRPC/NRR--2010/232.
---------------------------------------------------------------------------
Comment: We received numerous comments that EPA incorrectly used
the maximum annual visibility impacts occurring during any given year
of the 2001-2003 baseline period over which the Wyoming visibility
models are run. Commenters asserted that standard practice has been,
and continues to be, to average the results over the three year period
as the three year average is a more robust value than the single year
value used by EPA, and thus EPA should use longer term data. One
commenter pointed out that consistent with the principle of using
longer-term averages, baseline visibility conditions under the RHR are
determined by taking the average degree of visibility impairment for
the most and least impaired days for each of calendar years 2000
through 2004, and averaging the five annual values.
Response: We disagree with this comment. In our review of the
CALPUFF modeling results presented by Wyoming, we cited the change in
the maximum 98th percentile impact over the modeled three year
meteorological period (2001-2003). As the 98th percentile value is
intended to reflect the 8th high value in any year, it already
eliminates seven days per year from consideration in order to account
for short-term events, unusual meteorological conditions, and any over-
prediction bias in the model. We also note that our approach is
consistent with the method used by Wyoming in identifying subject-to-
BART sources, where a source is exempt from BART only if the modeled
98th percentile change is less than 0.5 deciview at all Class I areas
for each year modeled.\121\ That is, whether a source is subject to
BART is dependent on the maximum 98th percentile over the three year
modeled meteorological period, not the average across the three year
period. We find that it is reasonable to use the same approach when
considering the visibility improvements associated with control
options. Finally, we note that this approach is consistent with our
consideration of visibility improvement in other actions, such as our
FIP for Montana.
---------------------------------------------------------------------------
\121\ Chapter 6, Section 9(d)(i)(C) of the Wyoming Air Quality
Standards and Regulations.
---------------------------------------------------------------------------
Comment: EPA's use of the maximum values in its BART NOX
determinations for its regional haze FIP causes inflated visibility
impacts and over-estimated improvements being used. For example, if EPA
were to run its approved models, used its approved ammonia values for
the western states, and used the average visibility impact over the
three years rather than a maximum impact for a single year, the
incremental visibility impact between installing LNB technology and
SNCR at Wyodak and Dave Johnston Unit 3 drops to just 0.09 deciview.
Instead, EPA has used an improper evaluation to create an inflated
visibility improvement of 0.15 and 0.17 delta deciview to justify the
installation of the SNCR. As a result, EPAs' BART NOX
evaluations are
[[Page 5120]]
invalid. The modeling results reported by Mr. Paine using the actual
BART limits include values for each of the meteorological years 2001,
2002 and 2003, as well as the average values for the three years. All
of the values signify a negligible visibility improvement from SNCR.
Response: We have addressed each aspect of this comment in separate
responses to comments. In our previous proposal we performed CALPUFF
model simulations consistent with the approach specified in the Wyoming
protocol, but in this action we adopted updated model versions and used
lower ammonia background concentrations that are consistent with
monitoring data and IWAQM Phase 2 report. Regardless, as discussed in
section IV, in consideration of our revised cost of compliance and
visibility impact analyses, and of the remaining BART factors, we have
changed our final NOX BART determinations for both of the
units in question. We are no longer requiring SNCR for either Wyodak or
Dave Johnston Unit 4.
Comment: EPA's use of the cumulative deciview improvement from
several Class I areas overestimates the visibility improvement which
may reasonably be anticipated because visibility impacts from a BART
source may occur on different days at each Class I area. Adding the
numbers in Tables 47, 54, and 56 of EPA's proposed regional haze FIP
leads to the impression that a perceptible visibility improvement will
occur, when in reality none of the modeled visibility improvements
would be perceptible to the human eye.
Response: We disagree with this comment. In evaluating the
visibility improvement associated with various control options, EPA
interprets the CAA to require consideration of visibility improvement
at all impacted Class I areas. Consideration of improvement at multiple
Class I areas, as opposed to just benefits at the most impacted Class I
area, has often been described as ``cumulative visibility
improvement.'' Despite this terminology, however, an analysis of
cumulative visibility improvement does not necessarily require that the
deciview improvement at each area be summed together. While states or
EPA are free to take such a quantitative approach, they are also free
to use a more qualitative approach. Here, we chose to rely primarily on
the visibility improvement at the most impacted Class I area, while
also considering the number of additional Class I areas that would see
improvement, as well as the level of improvement at each area. We did
not expressly rely on a summation of visibility benefits across Class I
areas, as we have done in other regional haze actions, although, as the
commenter points out, this metric was included in some tables. Contrary
to the commenter's assertion, however, a summation of visibility
benefits is not intended to suggest that individually imperceptible
levels of improvement are somehow perceptible, but rather to provide a
single metric that can simultaneously capture both the number of Class
I areas affected and the magnitude of improvement at those areas for
comparison purposes. Moreover, we note that visibility improvement does
not need to be perceptible to be deemed significant for BART purposes.
We have responded in more detail to concerns regarding perceptibility
elsewhere in this document.
Comment: The commenter states that EPA's cumulative visibility
analyses ignore the discretion given to states in 70 FR 39107; Id. at
39123 (emphasis added); see also 77 FR 24768, 24774 (Apr. 25, 2012)
Response: As stated above, EPA primarily relied on the benefits at
the area with the greatest visibility improvement from controls, but we
also considered impacts and benefits at nearby areas included in the
modeling analysis. The consideration of visibility benefits over
multiple Class I areas is a useful metric that can further inform a
BART determination.
Comment: The BART rule provides no support for EPA's ``summation of
cumulative impacts'' approach. Rather, the BART rule makes clear that
the initial focus is expected to be on the ``nearest Class I area'' to
the facility in question. 70 FR 39104, 39162 (Separt 6, 2005). The BART
rules indicate that it is appropriate to take account impacts at not
only the nearest Class I area but also impacts at other nearby Class I
areas, not for the purposing of summing impacts at all of those areas,
but rather for the purpose of ``determin(ing) whether effects at those
(other) areas may be greater than at the nearest Class I area.'' Id.
The BART rule states: ``If the highest modeled effects are observed at
the nearest Class I area, you may choose not to analyze the other Class
I areas any further as additional analyses might be unwarranted.'' Id.
Response: See our response to comments above. In addition, the BART
Guidelines provide that states, or EPA in lieu of the state, have
discretion on how to assess visibility impacts.
Comment: The commenter states that the BART rule does not preclude
a state from taking into account, as part of a BART assessment for a
given facility, visibility impacts projected to occur in two or more
Class I areas that are attributable to that facility's emissions.
However, nothing in the rules requires such an analysis, and such
analyses are deceptive when used in a cumulative fashion. EPA did not
have the authority to disapprove Wyoming's visibility improvement
analyses on the grounds that EPA prefers a different approach than the
lawful and permissible approach taken by Wyoming. See Train v. Natural
Res. Def. Council, Inc., 421 U.S. 60, 79 (1975).
Response: See our response to comments above and elsewhere in this
document (e.g., Legal Issue section) regarding EPA's oversight
authority.
Comment: EPA has improperly failed to account for the very few
number of days of visibility impacts or the seasonal timing of when
those few impacts occur.
Response: EPA recognizes that the BART Guidelines allow states to
consider the timing of impacts in addition to other factors related to
visibility impairment. However, states are not required to do so, and
EPA is not required to substitute a source's desired exercise of
discretion for that of the states. Furthermore, when promulgating a
FIP, EPA stands in the shoes of the state. In that capacity, EPA is not
required to consider the seasonality of impacts and has chosen not to
do so here. Taking into account visitation contradicts the goal of the
regional haze rule of improving visibility on the 20 percent best and
worst days. Indeed, EPA believes that the experiences of visitors who
come to Class I areas during periods other than the peak visitation
season are important and should not be discounted.
Comment: A review of the unit-specific CALPUFF EPA modeling results
developed for the Mount Zirkel Wilderness Area provides a vivid example
of the over-estimation of visibility improvement that EPA is relying on
to justify the installation of hundreds of millions of dollars in
additional controls. The unit specific CALPUFF modeling would indicate
that adding SCR to these units would improve visibility in Mount Zirkel
by over seven deciviews.
However, the monitored data from 2001-2003 at Mount Zirkel tells a
completely different story. This is the same time period used in the
CALPUFF models to develop the deciview impacts for each Wyoming BART-
eligible unit and to project the visibility improvements associated
with the addition of control devices.
Looking at the three-year average monitored results, and assuming
that
[[Page 5121]]
the nitrates associated with the emissions from all sources (not just
the BART-eligible EGUs) are completely eliminated, only a 0.94 deciview
improvement would be expected. EPA attempts to justify over a billion
dollars in controls at eight PacifiCorp units by assuming more than
seven deciviews of improvement could be obtained from these eight units
when the actual monitored data indicates that only a 0.94 deciview
improvement would be possible if all nitrate was removed from all
sources. In essence, EPA's regional haze FIP fails to recognize that,
given the monitored nitrate impacts, the modeled visibility impacts are
obviously grossly exaggerated.
Response: We agree with some of these concerns--that the original
modeling performed by the State and EPA used a high background ammonia
concentration and did not correct for ammonia limiting conditions. This
particularly affected the model results in the western part of Wyoming
and Class I areas such as Bridger Wilderness Area.
We have addressed this concern by adopting a new modeling protocol
that makes several improvements in the model results, including the use
of the current regulatory version of the model, the use of Method 8 to
assess visibility impacts, the use of lower background ammonia
concentrations, and ammonia limiting correction for BART sources with
multiple units. We note that the model overprediction in our re-
proposed modeling analyses occurred at Class I areas affected by BART
sources in western Wyoming, in the region in which monitoring data
showed strong seasonal variability in ammonia concentrations. In
contrast, modeled nitrate impacts from BART sources in eastern Wyoming
were significantly lower than observed nitrate concentrations at
IMPROVE sites at Wind Cave and Badlands in western South Dakota.
There are several factors that make it challenging to directly
compare CALPUFF results to measured concentrations at IMPROVE
monitoring sites at Class I areas. Most significantly, the monitor
operates every third day, while the model predicts concentration each
day. Moreover, modeled visibility impacts from multiple BART sources
cannot be summed and directly compared to measured data as all BART
sources are unlikely to have their largest impacts on the same Class I
area on the same day. Additionally, the model 98th percentile impact
should be compared to the maximum observed monitoring data because the
highest 2% of model impacts are discarded to address concerns that the
model can overpredict visibility impacts.
Comment: The commenter cites a study by Terhorst and Berkman which
compared CALPUFF model predicted impacts of the Mojave Power Station at
the Grand Canyon to observed impacts after the facility was closed in
2005. The study concluded that there was virtually no evidence that the
(Mojave) closure improved visibility in the Grand Canyon, and the
commenter cites this conclusion as evidence of the unreliability of the
CALPUFF model.
Response: We disagree that the Mohave Power Plant study raises
questions about CALPUFF's reliability. The Nevada Division of
Environmental Protection performed CALPUFF modeling to estimate the
contribution of the Mohave Power Plant to visibility impairment at
Grand Canyon National Park. Consistent with the BART Guidelines, the
State used the CALPUFF model to evaluate the Mohave Power Plant
contribution to visibility impairment relative to natural visibility
conditions. Subsequently, after the Mohave Power Plant ceased
operating, Terhorst and Berkman analyzed changes in monitored sulfate
concentrations at the Grand Canyon and calculated the visibility
impacts of those changes relative to current degraded visibility
conditions. Terhorst and Berkman incorrectly concluded that the State's
previous CALPUFF modeling overpredicted the Mohave Power Plant
visibility impacts because Terhorst and Berkman failed to compare their
results to natural visibility conditions. EPA considered and rejected
comments on the proposed BART Guidelines that visibility impacts should
be evaluated to relative to current degraded visibility conditions and
concluded that ``[u]sing existing conditions as the baseline for single
source visibility impact determinations would create the following
paradox: the dirtier the existing air, the less likely it would be that
any control is required.'' (70 FR 39124). Because Terhorst and Berkman
failed to compare observed changes in sulfate concentration to natural
visibility conditions, their analysis does not support the commenter's
statement that CALPUFF is unreliable. This flaw in their analysis has
also been recognized in a paper that responded to their analysis.\122\
Finally, as presented above, the use of the CALPUFF model for regional
haze is a settled manner for which the time for judicial review has
passed.
---------------------------------------------------------------------------
\122\ W.H. White, R.J. Farber, W.C. Malm, M. Nuttall, M.L.
Pitchford, B.A. Schichtel, Comment on ``Effect of coal-fired power
generation on visibility in a nearby National Park (Terhorst and
Berkman, 2010)'', Atmospheric Environment 55 (2012) 173-178.
doi:10.1016/j.atmosenv.2012.02.076.
---------------------------------------------------------------------------
Comment: The commenter states that EPA's own studies document that
CALPUFF overstates results and cites a May 2012 EPA sponsored study of
CALPUFF that found ``the current and past CALPUFF model performance
evaluations were consistent with CALPUFF tending to overestimate the
plume maximum concentrations and underestimate plume horizontal
dispersion.''
Response: In the BART Guidance, EPA recognized concerns that
CALPUFF can overpredict visibility impacts in some cases, and
therefore, as explained above, adopted the use of the 98th percentile
modeled impact, rather than the maximum modeled impact, to address this
concern.
Comment: EPA appears to take contrary positions in Oklahoma, where
it modeled all visibility impairing pollutants together, and Wyoming,
where EPA said that, based on the State's modeling, EPA ``could not
ascertain what the visibility improvement would be from an individual
NOX or PM control option.''
Response: It appears that the commenter has confused (1) whether
all pollutants were modeled together; and (2) whether all emission
reductions were modeled together. All pollutants were modeled together
both in modeling performed by Wyoming and by EPA for BART sources in
Wyoming and Oklahoma, consistent with IWAQM Phase 2 report
recommendations and with the State of Wyoming modeling protocol. The
additional modeling performed by EPA was designed to evaluate
visibility improvements from certain emissions reduction technologies;
specifically, to compare the incremental benefits of SCR and SNCR. Each
of these model simulations by EPA also included all other visibility
impairing pollutants, so the approach used by EPA in Wyoming and
Oklahoma is consistent.
Comment: EPA found that SCR provided only a 0.36 delta deciview
incremental visibility improvement for Dave Johnston Unit 3, using EPA
modeling, with an incremental cost of $7,163.00 per ton. 78 FR 34777-
34778. EPA failed to justify in its proposed rule how a 0.36 delta
deciview improvement, or approximately one-third that humanly
detectible, justifies the tremendous cost of SCR. Likewise, EPA found
that installing SNCR at Dave Johnston Unit 4 results in an incremental
0.11 delta deciview improvement over Wyoming's BART determination at an
incremental cost of
[[Page 5122]]
$4,655. 78 FR 34781-34782. The alleged incremental visibility benefit
of installing SNCR at Wyodak is 0.12 delta deciview at an incremental
cost of $3,725 per ton. 78 FR 34784-34785. EPA provides no
justification for requiring such tremendous costs for such an
inconsequential visibility improvement that likely falls within
CALPUFF's margin of error. EPA's modeling approaches are inconsistent
because EPA has determined in other states that visibility improvements
greater than those used to justify SNCR at Wyodak are too small or
inconsequential to justify additional pollution controls. See 77 FR
24794 (0.27 deciview improvement termed ``small'' and did not justify
additional pollution controls in New York); 77 FR 11879, 11891 (0.043
to 0.16 delta deciview improvements considered ``very small additional
visibility improvements'' that did not justify NOX controls
in Mississippi); 77 FR 18052, 18066 (agreeing with Colorado's
determination that ``low visibility improvement (under 0.2 delta
deciview)'' did not justify SCR for Comanche units)). Tellingly, the
``low visibility improvements'' that Colorado found at the Comanche
units not to justify post-combustion NOX controls, as agreed
to by EPA, were 0.17 and 0.14 delta deciview. 77 FR 18066. In Montana,
where EPA issued a regional haze FIP directly, it found that a 0.18
delta deciview improvement to be a ``low visibility improvement'' that
``did not justify proposing additional controls'' for SO2 on
the source. 77 FR 23988, 24012. Here, EPA's actions requiring
additional NOX controls based on little to no additional
visibility improvement are arbitrary and capricious, especially when
EPA did not require additional NOX controls in other states
based on similar visibility improvements. This is particularly true in
Montana where EPA had direct responsibility for the regional haze
program.
Response: We disagree that visibility improvements at Dave Johnston
Unit 3 and Wyodak are ``too small or inconsequential to justify
additional pollution controls.'' While the visibility benefits at these
units are less than what is generally considered perceptible (1.0
deciview), they are not so low as to preclude selection of the
associated controls without any consideration of the remaining BART
factors. The BART Guidelines are clear that states should consider
visibility impacts that are less than perceptible: ``Even though the
visibility improvement from an individual source may not be
perceptible, it should still be considered in setting BART because the
contribution to haze may be significant relative to other source
contributions in the Class I area. Thus, we disagree that the degree of
improvement should be contingent upon perceptibility. Failing to
consider less-than-perceptible contributions to visibility impairment
would ignore the CAA's intent to have BART requirements apply to
sources that contribute to, as well as cause, such impairment.'' 70 FR
39129. When the visibility improvements are considered, we continue to
find that this level of improvement, when considered along with the
other statutory factors, justifies the selected BART controls.
Finally, regarding commenter's assertions that we are being
inconsistent, because the commenter is only specific about visibility
improvement, it is not possible for EPA to address in this response any
specific concerns. As articulated in our proposed rulemakings and
further explained in our responses to other comments, EPA's partial
approval and partial disapproval of the Wyoming Regional Haze SIP is
consistent with the CAA, the RHR, BART Rule, and EPA guidance. Our
determinations considered all five factors, not just visibility
improvement.
Comment: Although it is true that Wyoming did not model the
visibility impact of SNCR, that fact is no justification for
disapproving Wyoming's BART. Nothing in the BART Guidelines or
Wyoming's BART Modeling Protocol demands modeling of SNCR, and EPA
points to nothing in either document that requires modeling of SNCR.
Response: We disagree with this comment. The BART selection process
requires a comparison between all technically feasible control options,
not the evaluation of individual control technologies in isolation.
While the BART Guidelines do not specify the order in which control
options must be evaluated (e.g., beginning with the most stringent or
beginning with least stringent control), they do specify that the CAA
factors must be considered for all options: ``In the final guidelines,
we have decided that States should retain the discretion to evaluate
control options in whatever order they choose, so long as the State
explains its analysis of the CAA factors.'' 70 FR 39130. The only
exceptions are ``. . . if you find that a BART source has controls
already in place which are the most stringent controls available . .
.'', or ``. . . . if a source commits to a BART determination that
consists of the most stringent controls available . . .'' 70 FR 39165.
In these situations, it is not necessary to complete an analysis of all
five BART factors. Therefore, because neither of these criteria was
met, the State was required to perform an analysis of all five BART
factors for all technically feasible control options. As such, the
State's failure to consider the visibility impacts of SNCR did in fact
serve as appropriate grounds for EPA's disapproval of Wyoming's BART
determination.
Comment: EPA modeling shows no significant visibility improvement
from SNCR and without a significant improvement there can be no
justification for disapproving the State's BART for Laramie River
Station, and, to the contrary, EPA's modeling supports Wyoming's
rejection of SNCR and choice of LNB/OFA because SNCR provides
negligible visibility improvement.
Response: We have required new LNBs with OFA and SCR for the
Laramie River Station, not new LNBs with OFA and SNCR, which is the
control option addressed by the commenter. Accordingly, we do not find
that the comment is relevant to our action. Our revised modeling shows
that the visibility benefit of new LNBs with OFA and SCR for Laramie
River Units 1-3 is 0.57 deciviews, 0.53 deciviews, and 0.52 deciviews,
respectively. We continue to find that the visibility benefit, when
taking into consideration the remaining BART factors, justifies
installation of new LNBs with OFA and SCR.
Comment: Basin Electric submitted results based on more accurate
modeling than EPA, which show that actual visibility improvement from
SNCR would be substantially lower than assumed by EPA. There is no
justification for disapproving Wyoming's BART based on a modeled
visibility improvement that is such a small fraction of what is humanly
perceptible.
Response: As described in response to other comments, we agree that
the original modeling protocol adopted by the State was inconsistent
with the BART Guidelines, IWAQM Phase 2 report and newly available
ambient monitoring data, and in our revised modeling we adopted several
of the changes recommended by this commenter, including the use of
lower background ammonia concentration, a correction for ammonia
limiting conditions for multiple units located at a single BART source,
and the use of Method 8 for the evaluation of visibility impairment.
However, even using these model options, we still found significant
visibility impacts for SCR control at
[[Page 5123]]
Laramie River. Our results are generally consistent with the modeling
results submitted by the commenter which also show significant impacts.
As described in another response, while the visibility benefits at each
of these units individually are less than what is generally considered
perceptible (1 deciview), they are not so low as to preclude selection
of the associated controls without any consideration of the remaining
BART factors. The BART Guidelines are clear that States should consider
visibility impacts that are less than perceptible because these sources
may still contribute to cumulative visibility impairment.
Comment: EPA did not assert a failure to model NOX
impacts separately was a flaw in the Laramie River Station modeling,
although EPA did identify this as a flaw in PacifiCorp modeling.
Response: We agree that the State evaluated NOX impacts
separately for the control technologies that the State included in its
modeling, however, the State did not evaluate SNCR. The other
deficiencies in the State's visibility analysis, including the failure
to consider the visibility impacts of SNCR, were appropriate grounds to
disapprove the State's BART determination.
Comment: The Wyoming modeling did in fact isolate the impact on
visibility for NOX control alternatives. Wyoming held
SO2 and PM emissions constant at baseline levels while
modeling varying NOX emission rates for each of the
NOX control options.
Response: We agree with this comment. Nonetheless, as stated above,
the other deficiencies in the State's visibility analysis, which were
inconsistent with the BART Guidelines, including the failure to
consider the visibility impacts of SNCR, were appropriate grounds to
disapprove the State's BART determination.
Comment: EPA claims that Wyoming modeled the wrong emission rates.
EPA notes that in its cost analysis it calculated a new removal
efficiency for NOX control options that was different than
the removal efficiency calculated by Wyoming, and claims that
visibility modeling should have used the EPA efficiencies. However, EPA
does not explain how modeling with the different removal efficiencies
conflicts with the BART Guidelines or the CAA. As to SNCR, EPA argues
that the State assumed a higher removal efficiency and thus,
paradoxically, modeling with the State's removal assumption would yield
greater visibility improvement than modeling with EPA's values. No such
modeling was done, however. The State did no modeling for SNCR, so the
State's removal efficiency was never modeled. It is an enigma how EPA
can disagree with modeling with the different SNCR removal values when
such modeling was never performed.
Response: We disagree with this comment. The BART Guidelines are
clear on how removal efficiencies should be considered in the
visibility evaluation: ``Post-control emission rates are calculated as
a percentage of pre-control emission rates. For example, if the 24-hr
pre-control emission rate is 100 lb/hr of SO2, then the post
control rate is 5 lb/hr if the control efficiency being evaluated is 95
percent.'' 70 FR 39170. Therefore, because the control efficiencies
assumed by the State differed from those found by the EPA, they
affected the calculation of post-control emission rates for modeling
purposes (and thereby the consideration of visibility impacts).
In regard to SNCR, as conceded by the commenter, the State did not
provide the visibility impacts associated with the control option. As
discussed elsewhere, failure to assess the visibility impacts of a
technically feasible control option is in clear conflict with the
requirements of the CAA and BART Guidelines. This failure alone,
regardless of the control efficiency assumed for SNCR, was sufficient
grounds for us to reject the State's BART determination. Moreover, the
incorrect removal efficiency for SNCR assumed by the State adversely
affected their analysis of cost of compliance, another statutorily
required BART factor.
To put it simply, the State failed in the first instance by not
considering the visibility improvement of SNCR as required by the CAA
and BART Guidelines. When EPA corrected this deficiency by performing
the modeling ourselves, it was necessary for us to correct the removal
efficiency of SNCR (as discussed in response to other comments).
Comment: The State assumed that SCR would reduce NOX
emissions from 0.21 lb/MMBtu to 0.07 lb/MMBtu--a reduction of 0.14 lb/
MMBtu. EPA assumes SCR would reduce NOX emissions from 0.19
lb/MMBtu to 0.05 lb/MMBtu, a reduction of the same 0.14 lb/MMBtu. All
other things being held constant, the 0.14 lb/MMBtu reduction will in
both cases yield an identical reduction in the visibility impairing
concentration of nitrate particulate in a Class I area.
Response: We disagree with this comment. The CALPUFF model
simulations estimate the visibility impairment attributed to the
emissions in each control scenario, not the relative reduction in
different control scenarios. Therefore, an emissions rate of 0.07 lb/
MMBtu will have 40% greater total emissions and a larger visibility
impact than an emissions rate of 0.05 lb/MMBtu.
Comment: EPA argues that Wyoming should have used a baseline of the
maximum 24-hour average NOX emission rate during the
baseline years of 2001-2003, and instead used an annual average
baseline rate. The BART Guidelines do not mandate the use of the 24-
hour maximum but, rather, ``recommend that the State use the highest
24-hour average actual emission rate'' and that the states should have
flexibility when evaluating the fifth statutory factor. The BART
Guidelines by their express terms authorize states to use baseline
emissions other than the 24-hour maximum rate. Use of the 24-hour
maximum baseline is not mandatory, and not using that baseline is not a
failure to comply with any requirement in the Guidelines. EPA itself
used annual average pre-control and post-control emission rates to
model visibility impacts in its Nevada FIP rulemaking.
Response: We disagree with this comment. As stated in the preamble
to the BART Guidelines, ``the emissions estimates used in the
[visibility] models are intended to reflect steady-state operating
conditions during periods of high capacity utilization.'' 70 FR 39120.
As such, the BART Guidelines recommend excluding emissions during
periods of start-up, shutdown, or malfunction or estimating visibility
impacts based on a source's allowable emissions as this could inflate
the visibility impacts of a source. Rather, for sources such as power
plants where States have information on a source's daily emissions, the
BART Guidelines explains that an emission rate based on a source's
maximum actual emissions over a 24-hour period is an appropriate gauge
of a source's potential impact as it ensures that peak emission
conditions are reflected but would be unlikely to lead to an
overestimation of a source's potential impacts. Id. The BART Guidelines
state that in developing a modeling protocol, States should ``[u]se the
24-hour average actual emission rate from the highest emitting day of
the meteorological period modeled (for the pre-control scenario).'' Id.
and 70 FR 39170.
Wyoming did not do this. Instead, in assessing the improvement in
visibility associated with the use of controls in its BART
determinations, Wyoming used the visibility modeling performed by
PacifiCorp and Basin Electric for their facilities. Although these
companies used very different approaches to estimating the baseline
emission rate--
[[Page 5124]]
neither of which used the 24-hour average actual emission rate--the
State accepted the visibility modeling done by both and submitted the
results in the Wyoming SIP. Even if the commenter were correct that the
approach in the BART Guidelines is only recommended, the commenter has
not provided any explanation as to why the disparate approaches used in
the Wyoming SIP were appropriate for estimating the degree of
visibility improvement associated with controls. Wyoming similarly
provided no explanation as to why the varying approaches adopted by
Basin Electric and PacifiCorp were appropriate for assessing visibility
improvement. Moreover, the commenter has not established that the
baseline emission rates used by Wyoming would accurately reflect
visibility impacts associated with steady-state operating conditions
during periods of high capacity utilization. Obviously, baseline
emission rates reflecting periods of relatively lower capacity
utilization would tend to underestimate peak visibility impacts.
Consider for example the baseline emission rate used for Laramie River
Unit 1. There, the State used a daily emission rate equating to 6,320
tons per year,\123\ while, based on actual emissions data, the EPA used
a daily rate equating to 8,786 tons per year.\124\ Thus, the rate used
by the State reflects a period of considerably lower capacity
utilization that would therefore tend to underestimate peak impacts.
---------------------------------------------------------------------------
\123\ Wyoming Department of Environmental Quality Air Quality
Division BART Application Analysis AP-6047, Table 16, May 28, 2009.
\124\ Air Quality Modeling Protocol: Wyoming Regional Haze
Federal Implementation Plan, U.S. EPA, Table B.9, January, 2014.
---------------------------------------------------------------------------
Regarding the emissions rates used in the Nevada regional haze SIP,
the State did not use the 24-hour average of actual emissions from the
highest emitting day in its BART determination for Reid Gardner
Generating Station. 77 FR 50936, 50944 (Aug. 23, 2012). As part of its
review of the Nevada SIP, EPA performed new visibility modeling. In
that modeling exercise, EPA used Nevada's emission rates based on
annual averages. Please refer to a related comment and response in the
final action for that rule for a full discussion. See 77 FR 50944).
Following our review of comments in that rulemaking--including comments
that we should have used the Guidelines maximum 24-hour average of
emissions in our visibility modeling--we scaled our estimates of the
visibility impacts of controls based on the source's emissions using
the Guidelines maximum 24-hour average. We took these scaled visibility
impacts into account in our final action. Id. at 50945.
Comment: EPA did not use the 24-hour maximum rate for the modeling
it performed in 2012. As noted in Section VIII.C, it used the same
baseline emission rates used by the State. EPA-R08-OAR-2012-0026-0037.
EPA did not find the State's approach was a violation of the BART
Guidelines or was a reason to disapprove the State's modeling or BART
determination. Having sanctioned the use of a different baseline then,
EPA may not now claim it violates the BART Guidelines or a ground for
disapproving the State's modeling or BART determination.
Response: We agree that we did not use the 24-hour maximum [actual]
emission rates for modeling purposes in our original proposed rule
published in 2012. However, we did not finalize that rule, at least in
part, for the very reason that the baseline emission rates calculated
by Wyoming, and subsequently used by EPA in the 2012 proposed rule,
were inconsistent with the BART Guidelines. As we never finalized the
original rule, we disagree with the commenter's suggestion that we
somehow sanctioned Wyoming's approach. A proposed rule does not
represent final agency action.
Comment: The maximum improvement modeled by EPA that would be
achieved at any Class I area by adding SCR to the existing new LNB plus
OFA is 0.5 delta deciview. This is below the 1.0 delta deciview level
often cited as the lowest level of change that is humanly perceptible.
For EPA to propose disapproval of the State's BART based on an
imperceptible improvement is to propose disapproval based on a
nonmaterial factor.
Response: We disagree that the visibility improvements for Laramie
River or Jim Bridger are de minimis or too small to just justify the
expense of requiring controls. As discussed in response to another
comment, the BART Guidelines are clear that it is not necessary for the
visibility improvement of a particular control option to be above the
perceptible threshold. The regional haze program is premised on the
fact that numerous sources are contributing to visibility impairment
and numerous sources will need to reduce emissions in order to improve
visibility. We continue to find that this level of improvement, when
considered along with the other statutory factors, justifies the
selected BART controls.
Comment: The commenter states that EPA's modeled visibility
improvement overstates the improvement that would actually be achieved.
The commenter submitted new modeling showing that the visibility
improvement from further reductions of NOX emissions would
be much smaller than that predicted by EPA. AECOM corrected four of the
flaws in EPA's modeling and re-ran CALPUFF. The commenter submitted
refined modeling with four adjustments: 1. The use of seasonal
background ammonia concentrations; 2. Modeling of all units together
with correction for ammonia limited conditions; 3. Use of a post-
control emission rate of 0.07 lb/MMBtu, consistent with EPA's proposed
emission limit; and 4. The use of CALPOST Method 8. AECOM's revised
modeling was identical to EPA's in all other respects. The refined
modeling predicted that the incremental visibility benefit of SCR at
each of Laramie River Units 1, 2 and 3 would range between 0.20-0.24
delta deciview at either Badlands or Wind Cave National Park. The
actual visibility improvement of SCR would be even less than predicted
by the refined modeling because CALPUFF is known to substantially
overstate nitrate haze.
Response: We agree that our proposed modeling was inconsistent with
the BART Guidelines, IWAQM Phase 2 report and monitored data, and in
our revised final modeling we adopted several of the changes
recommended by this commenter, including the use of lower background
ammonia concentration, a correction for ammonia limiting conditions for
multiple units located at a single BART source, and the use of Method 8
for the evaluation of visibility impairment. However, even using these
less conservative model options, we still found significant visibility
impacts for SCR control at the Basin Electric Laramie River EGUs. We
did not use the seasonal background ammonia concentration proposed by
the commenter because we did not have sufficient ambient monitoring
data to determine the seasonal background concentrations in eastern
Wyoming.
Comment: The commenter states that nitrate haze occurs primarily in
the winter when few visitors are present in Class I areas. During the
peak summer visitation period, the impact of wildfires would overwhelm
any marginal visibility improvement that might be achieved by SCR. The
commenter cites an EPA report that stated ``[A] all else being equal,
impairment from anthropogenic sources is considerably more
objectionable during times of the year with greatest visitor attendance
(e.g., summer). Visibility objectives might, therefore, be stated in
terms of acceptable frequency distributions of visibility (e.g.,
contrast) over the course of a year.'' Source: Report to Congress under
CAA Section 169A(a)(3). The
[[Page 5125]]
commenter states that these factors further support Wyoming's decision
to reject SCR and SNCR as BART. These technologies would not improve
visibility on the worst haze days because Laramie River doesn't
contribute to haze on those days, and any slight visibility improvement
would occur in the winter season when few visitors enter the Class I
areas. Wyoming's decision to reject SCR as BART is therefore reasonable
and complies with the CAA.
Response: As discussed in response to another comment, EPA agrees
that nitrate impacts are more dominant in the winter. Nonetheless,
daily nitrate impacts from April through October are not trivial. EPA
also agrees that the BART Guidelines allow states to consider the
timing of impacts in addition to other factors related to visibility
impairment. However, states are not required to do so, and EPA is not
required to substitute a source's desired exercise of discretion for
that of the states. Furthermore, when promulgating a FIP, EPA stands in
the shoes of the state. In that capacity, EPA is not required to
consider the seasonality of impacts and has chosen not to do so here.
Taking into account visitation contradicts the goal of the regional
haze rule of improving visibility on the 20 percent best and worst
days. Indeed, EPA believes that the experiences of visitors who come to
Class I areas during periods other than the peak visitation season are
important and should not be discounted.
Comment: We received comments that our FIP was not warranted
because the cause of visibility impairment during the times of peak
visitation was wildfires and thus does not justify the control of
NOX from stationary sources.
Response: See response above.
Comment: Ammonia levels at the altitude of the plume would be lower
than the reported surface level ammonia concentrations, so less ammonia
would be available to form visibility-impairing nitrate.
Response: We disagree that there is compelling evidence that
background ammonia levels are significantly different at the altitude
of the plume compared to the surface. While there are limited studies
showing vertical gradients of ammonia in the troposphere,\125\ these
studies do not show a strong gradient within the planetary boundary
layer where the plume is typically located. Moreover, as discussed in
the response to another comment, it is necessary to evaluate the
combined concentrations of gas ammonia and particulate ammonium to
estimate the background ammonia level, so vertical gradients in
measured ammonia alone are not sufficient to specify the vertical
gradient in background ammonia. It is possible that decreasing
temperature with altitude could affect the thermodynamic equilibrium
between gas ammonia and particulate ammonium and that this could
contribute to observed vertical gradients in ammonia. It is also
possible that dry deposition of ammonia at the surface could create a
negative vertical gradient in ammonia near the surface. We recognize
that there are limited measurement studies available for total gas
ammonia and particulate ammonium, and as a result there is uncertainty
in the estimate of background ammonia. Given this uncertainty, we
believe it is appropriate to rely on measurement studies of total gas
ammonia and particulate ammonium when available and reliable as
explained elsewhere in this document (along with the IWAQM Phase 2
report default values), and to rely on the IWAQM Phase 2 report where
monitoring data are not available.
---------------------------------------------------------------------------
\125\ Levine et al., (1980) The Vertical Distribution of
Tropospheric Ammonia, Geophys. Res. Letters, vol. 7, No. 5, 17-32.
---------------------------------------------------------------------------
Comment: The commenter states that inventories show very low
ammonia concentrations in the corridors between Laramie River Station
and the relevant Class I areas.
Response: We disagree with the commenter's assertions. We note that
there is large uncertainty in estimates of ammonia emissions
inventories that are based on source activity data and emissions
factors. Moreover, even when more certain estimates of ammonia
emissions are available, it is not possible to estimate ambient ammonia
concentrations based on emissions inventory data alone. An estimate of
ambient ammonia levels would require an evaluation of modeled emissions
data and the effects of transport, dispersion and removal of ambient
ammonia. Direct measurements of ambient concentrations of gas ammonia
and particulate ammonium provide a more reliable estimate of background
ammonia than do model simulations of the emissions, transport,
dispersion and removal of ammonia.
Comment: The commenter states that reliable ammonia measurements
from the IMPROVE monitor located in the Wind Cave National Park were
published in September 2012. Chen et al, available at AECOM Report.
This monitor provides actual ground level ammonia data that is
representative of the Class I areas that are relevant to Laramie River
Station. AECOM Report at 4. EPA has given no explanation for its
assumption of a constant 2.0 ppb background concentration in this case.
Response: We evaluated the ammonia and ammonium monitoring data
submitted by the commenter in Exhibit 6, which is an extended abstract
presented at the 2010 conference in Whitefish, MT.\126\ The data are
from a pilot study conducted from April 2011 to January 2012 designed
to measure total NHX as the sum of ammonia and particulate
ammonium at 9 IMPROVE sites. The pilot study includes data for IMPROVE
monitoring sites at Wind Cave and Rocky Mountain National Park, which
are Class I areas for which we evaluated visibility impacts in this
action. We note that the pilot study data are for less than one full
year and are plotted in Figure 1 of the report as monthly average
concentrations. The measured values of NHX are not reported,
but the plot does show seasonal variation in NHX
concentrations, as expected, with higher NHX concentrations
in summer and lower concentrations in winter. Annual average
NHX concentrations cannot be estimated from the plot itself,
but they appear to be approximately consistent with the default IWAQM
ammonia background concentration of 0.5 ppb for forested areas. Given
that both the Rocky Mountain and Wind Cave Class I areas have
significant forest cover, the measurements in the pilot study appear to
be consistent with the IWAQM Phase 2 report.
---------------------------------------------------------------------------
\126\ Chen et al., A Pilot Monitoring Study of Atmospheric
NHX at Selected IMPROVE sites AWMA Aerosol and
Atmospheric Optics, Visibility & Air Pollution Conference, September
24-28, 2012, Whitefish, MT.
---------------------------------------------------------------------------
Measurements of NHx are not reported for Badlands
National Park, which is a mix of bare rock and mixed-grass prairie
ecosystems. Based on the IWAQM Phase 2 report, default background
ammonia concentrations in the range of 1 to 10 ppb at 20 degrees
Celsius would be appropriate for this region. We reviewed the ambient
ammonia monitoring data on which the IWAQM Phase 2 report was based,
and the data for grasslands were largely based on measurements at
Pawnee National Grassland, where average ammonia levels in summer were
10 ppb. Because the Pawnee National Grassland is located close to large
agricultural and livestock ammonia sources in eastern Colorado, it is
uncertain if the same ammonia levels would be appropriate for the more
Badlands area. Therefore, we selected a background ammonia
concentration of 1 ppb for CALPUFF modeling of BART sources that impact
the Wind Cave and Badlands Class I areas.
[[Page 5126]]
Comment: The commenter states that if EPA uses the maximum 24-hour
NOX emissions rate when modeling baseline visibility
impacts, it should also use the maximum 24-hour SO2 and
PM10 emissions rates for the baseline. NOX
competes with SO2 for ammonia to make either ammonium
nitrate or ammonium sulfate. Setting the SO2 baseline rate
at a low concentration relative to NOX skews the model to
predict the formation of more ammonium nitrate and less ammonium
sulfate. This magnifies the modeled benefits of reducing NOX
emissions.
Response: We agree that we did not use the maximum [actual] 24-hour
emission rates for SO2 and PM10 as we did for
NOX. However, we have not found based on our analysis, and
the commenter has not established, that doing so had any material
impact on the modeled benefits associated with NOX controls.
The BART sources in Wyoming that are covered in this action are
subject-to-BART only for NOX and PM. In addition, we
considered comments on, but did not question the validity of the
State's BART analyses for PM. In fact, as explained in detail elsewhere
in this document, with respect to the State's PM BART determinations,
the State's SIP and existing information was adequate to find that the
PM BART determinations were reasonable. Accordingly, the purpose of our
modeling effort was to identify the visibility improvement associated
with NOX controls, not SO2 or PM controls. And
so, in evaluating the visibility of NOX controls, we held
the SO2 and PM emissions constant at the rate associated
with the ``committed controls'' identified by the State. Therefore,
even if there was a discernible impact on the modeled visibility
benefit of NOX controls related to our treatment of modeled
emission rates for SO2 and PM, it would be common to all of
the modeled NOX control scenarios and would not have favored
one control option over another.
Comment: The visibility improvement from SCR will be much less than
EPA claims. The modeling preformed by AECOM and Wyoming produced
similar results, and both predicted much less visibility improvement
than EPA.
Response: The modeling performed by Wyoming used the 2 ppb
background concentration that was established in the State's protocol,
and this resulted in model visibility impacts that were significantly
greater than those estimated by AECOM in its modeling using lower,
seasonally varying background ammonia concentrations. The ammonia
concentrations in ppb used in the AECOM modeling for the months of
January December were as follows: 0.3, 0.9. 0.9, 1.0, 1.0, 2.0, 2.0,
1.0, 0.8, 0.8, 0.6, and 0.3. We note that our modeling results in our
original proposal also used the State's protocol, and our model results
were identical to the State's modeling results for the emissions
scenarios that both the State and EPA evaluated. The EPA modeling
results in our revised proposal showed larger visibility impacts
because we corrected the baseline emissions rates to make the emissions
consistent with the BART Guidance. In the new modeling results that we
performed using our revised final EPA Protocol and included in this
action, we used a model configuration that is generally consistent with
modeling submitted by the commenter. The revisions to the protocol
include reduced background ammonia, correction for ammonia limiting
conditions, updated regulatory versions of the model, and the use of
Method 8. The commenter did not submit model results for all emissions
scenarios in a format that can be directly compared to our tabulated
model results, but our revised model results in this action appear to
be generally consistent with the commenter's model results, and these
results do show that SCR at Basin Electric Laramie River has
appreciable visibility benefit at the Wind Cave and Badlands Class I
areas.
Comment: The commenter states that the version of CALPUFF used by
Wyoming and EPA (version 5.711a) relies on simplified chemistry
algorithms that overstate nitrate formation and overpredict visibility
impacts, and that EPA acknowledges that ``the simplified chemistry in
the [CALPUFF] model tends to magnify the actual visibility effects of
[a] source.'' 70 FR 39121. Papers by Morris et al. and Karamchandani et
al. show that CALPUFF chemistry overpredicts nitrates by a factor of 2-
to-4 times in winter.
Response: As described in responses to other comments and in our
modeling protocol, EPA used the currently approved CALPUFF version 5.8
for modeling used in this action. EPA has acknowledged in the BART
Guidelines that there is uncertainty in the CALPUFF modeled visibility
impacts. EPA recognized the uncertainty in the CALPUFF modeling results
when EPA made the decision, in the final BART Guidelines, to recommend
that the model be used to estimate the 98th percentile visibility
impairment rather than the highest daily impact value. While
recognizing the limitations of the CALPUFF model in the BART Guidelines
Preamble, EPA concluded that, for the specific purposes of the Regional
Haze Rule's BART provisions, CALPUFF is sufficiently reliable to inform
the decision making process.
Comment: The commenter states that a study by the CDPHE showed
model results for nitrates will be skewed high by assuming higher than
actual background levels of ammonia.
Response: The CDPHE completed a CALPUFF model sensitivity study
that evaluated the effect of the background ammonia concentration on
model predictions for ammonium nitrate and sulfate. The CDPHE found
that CALPUFF model predicted nitrate was insensitive to variations in
background concentrations greater than 10 ppb and became progressively
more sensitive to background ammonia as it was reduced from 10 to 0
ppb.\127\ We note that CDPHE performed a sensitivity study but did not
evaluate model performance and did not identify any particular case in
which model performance was skewed by the use of inappropriate
background ammonia concentrations. The conclusions of the CDPHE study
are fully consistent with the IWAQM Phase 2 report, which also
recognized that accurate specification of background ammonia ``is
critical to the accurate estimation of particulate nitrate
concentrations.'' \128\
---------------------------------------------------------------------------
\127\ CDPHE, Ibid.
\128\ IWAQM, page 14 and page 21
---------------------------------------------------------------------------
Comment: The commenter cites several presentations and studies that
document flaws in CALPUFF's sulfate and nitrate chemistry: (1) It is
out of date, overly simplistic, and inaccurate; (2) CALPUFF greatly
overstated sulfate and nitrate in winter, overestimating visibility
impacts by 100-1000% in many cases; and (3) that the model understated
sulfate in summer; and that nitrate predictions were particularly
inaccurate, overstated, and unreliable.
Response: EPA recognized the uncertainty in the CALPUFF model when
EPA made the decision, in the final BART Guidelines, to recommend that
the model be used to estimate the 98th percentile visibility impairment
rather than the highest daily impact value. While recognizing the
limitations of the CALPUFF model in the BART Guidelines, EPA concluded
that, for the specific purposes of the RHR's BART provisions, CALPUFF
is sufficiently reliable to inform the decision making process.
Comment: NOX emissions control has little visibility
benefit during summer when visibility impairment is dominated by
wildfires.
Response: EPA agrees that nitrate impacts are more dominant in the
winter. The CALPUFF model results are
[[Page 5127]]
consistent with these observations, with the largest modeled visibility
improvements occurring from late fall to early spring. NOX
emissions are precursors to ammonium nitrate, and high concentrations
of ammonium are typically observed from late fall to early spring when
cold temperatures and high relative humidity results in thermodynamic
conditions that favor the formation of ammonium nitrate. Observed
ammonium nitrate concentrations are typically low during summer because
warm temperatures result in thermodynamic conditions that are not
favorable to the formation of ammonium nitrate. Nonetheless, there may
be higher nitrate concentrations on colder days during this period.
Comment: EPA's visibility-benefits analysis still is constrained in
the re-proposed Wyoming haze plan because EPA has not identified the
visibility benefits from BART controls across all of the Class I areas
affected by haze-causing pollutants from Wyoming sources. Wyoming EGUs
impact visibility over at least 18 Class I areas. While EPA's own
visibility modeling fully supports determinations that SCR is BART for
all Wyoming EGUs, the visibility benefits of SCR across all affected
Class I areas are cumulatively significant and, if the RHR's
fundamental purpose is to be fulfilled, they must not be ignored.
Response: EPA disagrees with this comment. The commenter's number
of ``at least 18 Class I areas'' is derived by including Class I areas
that are more than 300 km from BART sources. EPA disagrees that these
Class I areas should be included in the visibility analysis. The IWAQM
Phase 2 report reviewed model performance evaluations of CALPUFF as a
function of distance from the source and concluded that:''Based on the
tracer comparison results presented in Section 4.6, it appears that
CALPUFF provides reasonable correspondence with observations for
transport distances of over 100 km. Most of these comparisons involved
concentration values averaged over 5 to 12 hours. The CAPTEX
comparisons, which involved comparisons at receptors that were 300 km
to 1000 km from the release, suggest that CALPUFF can overestimate
surface concentrations by a factor of 3 to 4. Use of the puff splitting
option in CALPUFF might have improved these comparisons, but there are
serious conceptual concerns with the use of puff dispersion for very
long-range transport (300 km and beyond). As the puffs enlarge due to
dispersion, it becomes problematic to characterize the transport by a
single wind vector, as significant wind direction shear may well exist
over the puff dimensions. With the above thoughts in mind, IWAQM
recommends use of CALPUFF for transport distances of order 200 km and
less. Use of CALPUFF for characterizing transport beyond 200 to 300 km
should be done cautiously with an awareness of the likely problems
involved.'' \129\ We present additional discussion of this issue in our
response to the following comment.
---------------------------------------------------------------------------
\129\ IWAQM, p.18.
---------------------------------------------------------------------------
Comment: EPA arbitrarily failed to model visibility impacts of the
various control options at all affected Class I areas, including those
that are beyond 300 km from the source. EPA recently responded to a
similar comment in its final action promulgating the Montana Regional
Haze FIP, 77 FR 57864, for the first time supporting its truncated
modeling by referencing a now-discredited 1998 report regarding CALPUFF
performance. Because EPA raised this issue only after the close of the
public comment period on its Wyoming regional haze action, EPA should
consider the Conservation Organizations' response. See 42 U.S.C.
7607(d)(4)(B)(i).
In its response to public comments on the Montana FIP, EPA stated,
``The Interagency Workgroup on Air Quality Modeling (IWAQM) Phase 2
report (EPA, 1998) reviewed model performance evaluations of CALPUFF as
a function of distance from the source and concluded that: . . .[u]se
of CALPUFF for characterizing transport beyond 200 to 300 km should be
done cautiously with an awareness of the likely problems involved.'' 77
FR 57867-68. EPA then concludes, ``[t]herefore, given that the IWAQM
guidance provides for the use of the CALPUFF model at receptor
distances of up to 200 to 300 km, and given that EPA has already
addressed uncertainty in the CALPUFF model, we believe it is reasonable
to use CALPUFF to evaluate visibility impacts up to 300 km.'' Id. at
57868.
We agree that CALPUFF is reliable at distances of 300 km. However,
EPA's use of the IWAQM Phase 2 report to support its decision to
exclude modeling at distances beyond 300 km is arbitrary. First,
changes to CALPUFF since 1998 may correct problems identified in the
IWAQM Phase 2 report with modeling accuracy in the 200-1,000 km range.
Second, a more recent study prepared for EPA called into question the
conclusions of the IWAQM Phase 2 report upon which EPA relies. See Long
Range Transport Models Using Tracer Field Experiment Data (May 2012)
(EPA Contract No: EP-D-07-102, Work Assignment No: 4-06). The May 2012
study concluded that ``The inability of most (~90%) of the current
study's CALPUFF sensitivity tests to reproduce the 1998 EPA study
tracer test residence time on the 600 km receptor arc is a cause for
concern.'' Not only were the authors of the May 2012 study unable to
reproduce the 1998 study's findings that CALPUFF overestimated
pollutant concentrations at distances of 600 km, the 2012 study
concluded that CALPUFF actually underestimates average pollutant
concentrations at 600 km. Accordingly, reliance on CALPUFF at long
distances would result in conservative estimates of visibility impacts.
It is not appropriate to assume, as EPA effectively did in its Wyoming
proposal, that such impacts are non-existent. EPA's failure to model
and consider visibility impacts at all affected Class I areas,
including those beyond 300 km, is not supported.
Because the RHR, and SIPs and FIPs promulgated to implement it, are
to fulfill CAA requirements to mitigate and ultimately eliminate
anthropogenic sources of haze pollution at all Class I national parks
and wilderness areas, it is imperative that states and EPA use models
to completely and accurately depict the visibility impact of a source
to the region's Class I areas as well as projected benefits from BART.
In this regard, the conclusion of the May 2012 study that CALPUFF
reliably (if conservatively) identifies visibility impacts to Class I
areas beyond those previously evaluated are critical, and directs EPA
to supplement the incomplete analysis presented in its proposed action
on the Wyoming Regional Haze plan with additional modeling, or consider
the more complete modeling submitted by the conservation organizations
with their August 2, 2012 comments.
Response: EPA disagrees with the commenter's assertion that changes
to CALPUFF now support modeling at distances greater than 300 km. The
commenter cited a May 2012 technical evaluation (Documentation of the
Evaluation of CALPUFF and Other Long Range Transport Models Using
Tracer Field Experiment Data \130\) that evaluates several long range
transport models based on several tracer studies. The report cited by
the commenter does not refute the IWAQM Phase 2 report which states
that ``IWAQM recommends use of CALPUFF for transport distances of order
200 km and less. Use of CALPUFF for characterizing transport
[[Page 5128]]
beyond 200 to 300 km should be done cautiously with an awareness of the
likely problems involved.'' \131\ In fact, the May 2012 report further
``emphasizes the need for a standardized set of options for regulatory
CALPUFF modeling.'' \132\ Given these findings, EPA does not agree, as
the commenter asserts, that it must consider CALPUFF modeling results
from Federal Class I areas beyond 300 km. EPA therefore believes that
the results of CALPUFF modeling beyond 300 km of the source should be
evaluated in light of the limitations discussed in the two guidance
documents cited above.
---------------------------------------------------------------------------
\130\ https://www.epa.gov/scram001/reports/EPA-454-R-12-003.pdf.
\131\ https://www.epa.gov/scram001/7thconf/calpuff/phase2.pdf,
page 18.
\132\ https://www.epa.gov/scram001/reports/EPA-454-R-12-003.pdf,
page 10.
---------------------------------------------------------------------------
Finally, we disagree that there is any notice issue with respect to
the commenter's allegations that EPA referenced the 1998 IWAQM study
for the first time in our response to comments in our Montana FIP
action. As quoted above, the BART guidelines specifically reference the
1998 IWAQM study with respect to CALPUFF settings.
Comment: EPA modeled visibility benefits at four Class I areas, and
demonstrated visibility improvement due to SCR that approximately
doubled the improvement afforded by SNCR at every Class I area modeled.
78 FR 34775-34776. EPA properly took account of the cumulative
visibility improvement across all four modeled Class I areas for each
unit, id. at 34776, but in fact, as the Conservation Organizations
commented previously, see 8/2/2012 Conservation Organization Comments,
SCR affords visibility benefits across at least six Class I areas.
Thus, the cumulative visibility benefits are even greater than found by
EPA, and further support a determination that SCR is BART for Laramie
River Station Units 1-3.
Response: We disagree that we should have evaluated visibility
impacts at all of the areas that the commenter considered in its
analysis. The commenter provided CALPUFF model results at 18 areas,
including areas that are not mandatory Class I areas, and at Class I
areas at distances greater than 300 km from Laramie River Station. In
our analysis of visibility impacts, we considered the visibility
improvement at four Class I areas within 300 km of the Laramie River
Station. Therefore, our modeling analyses did not ignore the visibility
improvement that would be achieved at areas other than the most
impacted Class I area, and we disagree with the assertion that we
should have evaluated all of the areas that the commenter considered.
Comment: EPA's re-proposed Wyoming haze plan presents a unit-by-
unit analysis of the visibility benefits of the installation of various
BART control alternatives at Wyoming EGUs, and identifies benefits at
only a subset of the affected Class I areas. However, EPA did not
present evidence of the cumulative visibility benefits that would be
enjoyed by Class I areas from implementation of all of the BART
determinations in its 2013 re-proposal. To assess this shortcoming, the
Conservation Organizations contracted with Howard Gebhart to conduct a
cumulative visibility improvement modeling analysis that compared
installation of the NOX BART determinations found in EPA's
2013 re-proposal versus the State BART determinations found in the
Wyoming Regional Haze SIP. See Gebhart Report, at 17-24. Mr. Gebhart's
visibility modeling results show that installation of the BART
determinations in EPA's 2013 re-proposal will result in significant
visibility improvement at numerous Class I areas when compared to the
Wyoming SIP. For example, installation of the BART determinations in
EPA's 2013 re-proposal would consistently result a total deciview
improvement of 1.0 deciview or greater over the Wyoming SIP at Badlands
National Park, Savage Run Wilderness, and Wind Cave National Park. In
addition, significant visibility improvements exceeding 0.5 deciviews
were predicted at Badlands National Park, Bridger Wilderness, Mount
Zirkel Wilderness, Rawah Wilderness, Rocky Mountain National Park,
Savage Run Wilderness, and Wind Cave National Park. In summary, the
Conservation Organizations' cumulative visibility improvement modeling
analysis provides further support that significant visibility benefits
can be achieved from the finalization of the BART determinations
contained in EPA's 2013 re-proposal. EPA's 2013 re-proposed rule
advances (without entirely fulfilling) the goals of the regional haze
program to reduce visibility impairment using BART during the first
regional haze five-year planning period. In contrast, the Wyoming
Regional Haze SIP would fall far short of these goals.
Response: First, we note that the modeling performed by the
Conservation Organizations' contractor used the 2 ppb background
ammonia concentration, and did not correct the model results for
ammonia limiting conditions, and therefore predicts greater visibility
impairment than did EPA's revised modeling. EPA provided information
about the visibility improvement modeled for different BART scenarios
at multiple Class I areas within 300 km of each BART source. EPA
primarily relied on the benefits at the area with the greatest
visibility improvement from controls, but we also considered the
cumulative impacts and benefits at multiple Class I areas. EPA agrees
that considering cumulative visibility benefits by aggregating the
expected improvement from over multiple Class I areas is a useful
metric that can further inform a BART determination. Such an approach
can be useful, for example, in simplifying a complex array of
visibility impacts, especially where a source has significant impacts
on multiple Class I areas.
Comment: EPA's proposed rule fails to present the cumulative
visibility benefits of installation of SCR at Wyoming's EGUs. Instead,
EPA only presents the visibility benefits for a single Class I area per
source (Wind Cave National Park for all sources except the Jim Bridger
plant (Mount Zirkel Wilderness Area)). The cumulative impact of a
source's emissions on visibility as well as the cumulative benefit of
emission reductions is a necessary consideration as part of the fifth-
step in the BART analysis. The statutory direction and goal of the
regional haze program is to remedy any existing impairment of
visibility in mandatory Class I areas. 42 U.S.C. 7491(1). The
implementing regulations plainly anticipate the need to reduce impacts
in multiple Class I areas, including those outside a state's borders,
and the obligation to assess what is necessary to do so. 40 CFR
51.308(d)(3). Further, states are required to establish reasonable
progress goals for each Class I area, not just the one most impacted by
a single source. Id. section 51.308(d)(1). EPA's own regional haze
guidance document states that a cumulative visibility benefit analysis
is generally consistent with the CAA. 70 FR 39105, 39107 (we believe
that a State's decision to use a cumulative analysis at the eligibility
stage is consistent with the CAA); 40 CFR Part 51, App Y. While the
Guidelines also contemplate and even allow analysis of only the most
impacted Class I area, such an analysis contradicts the regional
approach towards the restoration of visibility. Moreover, given the
number of Class I areas impacted by Wyoming sources, it is illogical
and baseless to fictitiously limit the spectrum of source impact and
emission control benefit. Based upon the guidance and the requirements
of the CAA, the cumulative impact of a source's
[[Page 5129]]
emissions on visibility, as well as the cumulative benefit of emission
reductions, should be considered as part of the fifth-step in the BART
analysis. The FLMs, too, have urged EPA Region 8 to consider the
cumulative visibility benefits of requiring stricter controls on BART-
eligible units in Montana. For example, at a public meeting in
Billings, regarding the Montana Regional Haze SIP, Valerie Naylor,
Superintendent of Theodore Roosevelt National Park stated, ``EPA placed
too much emphasis on incremental costs and incremental benefits, while
eliminating consideration of cumulative benefits that would be realized
in the numerous Class I National Parks, National Wildlife Refuges, and
Wilderness Areas impacted by Colstrip.'' The National Park Service
(NPS) has consistently requested that cumulative visibility benefit
analyses be conducted in other regional haze determinations. In
addition, EPA must consider the cumulative visibility benefit of BART
controls on multiple units of a single source. EPA's BART guidelines
make clear that states must consider emissions from an entire source in
determining whether a source is subject to BART, and further clarify
that multiple units at a single utility constitute a single source. 40
CFR Part 51, App Y, sect. II.A.
The Conservation Organizations retained Air Resource Specialists,
Inc. (ARS) to evaluate the cumulative visibility impact of
NOX BART controls, and found that the cumulative benefit of
SCR at all Wyoming BART-subject EGUs is very significant. In conducting
its supplementary modeling, ARS used an SCR-controlled NOX
emission rate to 0.05 lb/MMBtu to reflect the level of control
achievable with SCR and recalculated baseline emissions to comply with
the BART guidelines, as described in sections I.A.2 and I.C. Otherwise,
ARS employed the same assumptions used by EPA in its analysis.
ARS's visibility modeling addresses impacts to 18 Class I areas,
including Savage Run Wilderness Area (which is not a mandatory Class I
area but is managed as such by Wyoming). The ARS report addresses the
cumulative benefit of installation of SCR at multiple units at a single
power plant location (ex. the cumulative benefits of installation of
SCR at all four Bridger units). The ARS Report also calculates the
cumulative visibility benefit of installation of SCR on all BART units
in Wyoming. Id. It should not be assumed that ARS's results document
the highest impacts. Rather, they are presented to demonstrate
widespread and far-reaching visibility impacts and improvements that
can be achieved through the use of SCR.
The cumulative visibility benefit from installation of SCR on all
BART units in Wyoming is significant. The application of SCR control on
Wyoming's subject-to-BART emission units is predicted to improve worst-
case visibility impairment by up to 8 deciviews at the Savage Run Class
I area, with 4 deciviews of improvement or better at six Class I areas.
ARS Report, Table 3-13. For the 98th percentile day, the improvement
after SCR emissions control at all Wyoming BART-subject EGUs is as high
as 3.5 deciviews at Wind Cave National Park. Id. At least six different
Class I areas show improvement of 3 deciviews or more based on the 98th
percentile day after SCR emissions control at all Wyoming BART-subject
EGUs. Id.
SCR controls at Wyoming's subject-to-BART units are also predicted
to significantly reduce the number of days with visibility impacts
above 0.5 deciview and 1.0 deciview compared to baseline emissions
scenario. Over all 18 Class I areas modeled, the cumulative improvement
from application of SCR on all Wyoming BART-subject EGUs is 721 fewer
days with visibility impairment exceeding 0.5 deciview and 595 fewer
days with visibility impairment exceeding 1.0 deciview. Id., Table 3-
14. These improvements are relatively uniformly distributed across the
seven Class I areas most impacted by Wyoming's subject-to-BART EGUs:
Badlands National Park, Bridger Wilderness Area, Mt. Zirkel Wilderness
Area, Rawah Wilderness Area, Rocky Mountain National Park, Savage Run
Wilderness Area, and Wind Cave National Park.
Response: As described in another response, EPA did not limit its
analysis of visibility impairment to a single Class I area. We
evaluated visibility impairment from each BART source at multiple Class
I areas. We presented the results for each Class I area, and we
considered the visibility impairment at multiple Class I areas in our
BART determination. The estimates of visibility impairment presented by
the commenter relied on an overly conservative estimates of background
ammonia concentrations, and therefore are likely to overestimate
cumulative visibility benefits.
In regard to the comment concerning the cumulative visibility
benefit of BART controls on multiple units at a single source, see the
response to a subsequent comment below.
Comment: It is appropriate to consider both the degree of
visibility improvement in a given Class I area as well as the
cumulative effects of improving visibility across all of the Class I
areas affected. If reducing emissions from a BART source impacts
multiple Class I areas, then a BART determination should incorporate
those benefits. It is not justified to evaluate impacts at one Class I
area, while ignoring others that are similarly significantly impaired
by the BART source. If emissions from the BART source are reduced, the
benefits will be spread well beyond only the most-impacted Class I
area, and these benefits are an integral part of the BART
determination. The BART Guidelines attempt to create a workable
approach to estimating visibility impairment. The Guidelines do not
attempt to address the geographic extent of the impairment, but in
effect assume that all Class I areas are created equal, i.e.,
widespread impacts in a large Class I area and isolated impacts in a
small Class I area are given equal weight for BART determination
purposes. To address the problem of geographic extent, we look at the
cumulative impacts of a source on all Class I areas affected, as well
as the cumulative benefits from reducing emissions. While there may be
more sophisticated approaches to this problem, we believe that this is
the most practical, given current modeling techniques and information
available.
Response: Contrary to the commenter's assertion, we did assess
cumulative visibility impacts for multiple Class I areas. In our
analysis of visibility impacts, we considered the visibility
improvement at multiple Class I areas within the 300 kilometers of the
modeling domain. For example, in our analysis of BART control options
for Naughton, we considered the visibility improvement at seven Class I
areas (Bridger Wilderness Area, Fitzpatrick Wilderness Area, Grand
Teton National Park, North Absaroka Wilderness Area, Teton Wilderness
Area, Washakie Wilderness Area, and Yellowstone National Park).
Therefore, our proposed rule did not ignore the visibility
improvement that would be achieved at areas other than the most
impacted Class I area, and we disagree with the assertions that we did
not consider the impacts at multiple Class I areas. In the proposed
rule, we did however focus on the visibility benefits at the most
impacted Class I area.
Comment: EPA has incorrectly estimated visibility improvement from
all NOX control options at the Laramie River Station.
Wyoming DEQ evaluated visibility improvements at the two nearest Class
I areas and reported the
[[Page 5130]]
``The cumulative visibility improvement for SCR, as compared to LNB/
OFA, across Wind Cave National Park and Badlands National Park (based
on the 98th percentile modeled results) was 0.52-0.54 delta deciview
for each of the three units.'' EPA R8 evaluated the five closest Class
I areas but reported results for only the Wind Cave National Park.
Response: As described in a previous response, in our analysis of
visibility impacts, we considered the visibility improvement at four
Class I areas within 300 kilometers of Laramie River. Modeling results
for all Class I areas considered for each BART source for the re-
proposal were available to the public during the comment period upon
request. (See ``Summary of EPA's Additional Visibility Improvement
Modeling''). Therefore, our proposed rule did not ignore the visibility
improvement that would be achieved at areas other than the most
impacted Class I area, and we disagree with the assertions that we did
not consider the impacts at multiple Class I areas. In the proposed
rule, we did however focus on the visibility benefits at the most
impacted Class I area.
Comment: EPA rejected Oklahoma's visibility analyses which ``relied
upon pollutant specific modeling to evaluate the benefits from the use
of available SO2 emission controls.'' 76 FR 81728, 81740.
Rather, EPA modeled in Oklahoma ``all visibility impairing pollutants
to fully assess the visibility improvement anticipated from the use of
controls.'' EPA argued this modeling took into account ``the complexity
of atmospheric chemistry and chemical transformation among
pollutants.'' In Wyoming, EPA noted that Wyoming provided ``visibility
improvement modeling results that combine[d] the visibility improvement
from NOX, PM and SO2 control options'' and that
``EPA could not ascertain what the visibility improvement would be from
an individual NOX or PM control option.'' 77 FR 33031. EPA
appears to take contrary positions in Oklahoma and Wyoming. EPA's
inconsistent positions are arbitrary and capricious.
Response: As described in a response to a previous comment, it
appears that the commenter has confused (1) whether all pollutants were
modeled together; and (2) whether all control technologies were
modeled. All pollutants were modeled together both in modeling
performed by Wyoming and by EPA for BART sources in Wyoming and
Oklahoma, consistent with IWAQM Phase 2 report recommendations. The
additional modeling performed by EPA was designed to evaluate
visibility improvements from certain emissions reduction technologies.
Each of these simulations also included all other visibility impairing
pollutants, so the approach used by EPA in Wyoming and Oklahoma is
consistent.
Comment: We are concerned about the emissions modeled by EPA as
presented in the ``Summary of EPA's Additional Visibility Improvement
Modeling.'' For example, sulfuric acid mist
(H2SO4) emissions from each PacifiCorp unit are
assumed to double from the baseline and control scenarios that do not
include SCR versus scenarios with SCR. The only explanation provided by
EPA is that ``the emission rate for . . . total sulfate rates were
increased to account for the additional production that results from
SCR controls.'' EPA's approach in Wyoming is not consistent with its
approach elsewhere. For example, in its modeling analysis of addition
of SCR at Colstrip Units 1 and 2 in Montana, EPA assumed no additional
sulfate emissions from the addition of SCR.
Because H2SO4 must be reported as a hazardous
air pollutant, the Electric Power Research Institute has developed a
widely-accepted method for estimating those emissions. Our analyses
indicate a two-orders-of-magnitude overestimation by EPA of these
visibility-impairing emissions, which results in an underestimation of
the visibility benefit of adding SCR.
Response: While the method established by the Electric Power
Research Institute may yield more accurate H2SO4
emission rates, we have not found, and the commenter has not
substantiated, that our treatment of H2SO4 led to
meaningfully different modeled visibility improvement, or for that
matter, influenced the BART determination in a material manner. In the
modeling conducted by EPA, we set the sulfuric acid emission rates
equal to those in the State's modeling analyses which typically doubled
the H2SO4 emission rate between the baseline and
SCR modeling scenarios. In comparison to the emission rates for
SO2 and NOX, the emission rates for
H2SO4 were trivial. For example, consider Dave
Johnston Unit 3, where the modeled emission rates for SO2
and NOX in the baseline scenario were 420.0 lbs/hr and
1671.0 lbs/hr, respectively, while the modeled emission rate for
H2SO4 was 2.6 lbs/hr. Here, in comparison to
SO2 and NOX emissions, the emissions rate of
H2SO4 is clearly insignificant and would have a
limited impact on modeled visibility. The same can be said for the SCR
scenario where the modeled emission rates for SO2 and
NOX were 420.0 lbs/hr and 163.3 lbs/hr, respectively, while
the modeled emission rate for H2SO4 was 5.1 lbs/
hr. In short, the H2SO4 emission rates used in
the modeling were so low that it is apparent that they have no more
than a negligible impact on the modeled visibility improvement.
Comment: EPA must consider the cumulative visibility benefit of
BART controls on multiple units of a single source. EPA's BART
guidelines make clear that states must consider emissions from an
entire source in determining whether a source is subject-to-BART, and
further clarify that multiple units at a single utility constitute a
single source. 40 CFR part 51, App Y, sect. II.A. This is not by
accident or oversight. As EPA stated in its preamble to the BART
Guidelines, ``[a]pplying de minimis levels on a unit by unit basis . .
. could exempt hundreds of tons of emissions of a visibility-impairing
pollutant from BART analysis. [I]t is possible that while emissions
from each unit are relatively trivial, the costs of controlling
emissions from multiple units might be cost-effective in light of the
BART-eligible source's total emissions of the pollutant at issue.'' 70
FR 39104, 39117. With respect to the RHR requirement that states must
project visibility impacts of BART controls, the BART Guidelines state:
``Once you have determined that your source or sources are subject to
BART, you must conduct a visibility improvement determination for the
source(s) as part of the BART determination.'' 40 CFR part 51, App Y,
sect. IV.D.5. Thus, it is clear that both visibility impacts and
visibility benefits are to be considered cumulatively for multiple
units at a single source.
This is also consistent with EPA's practice in other states. For
example, EPA found it appropriate to consider the combined visibility
impact of pollution controls on multiple units at a single facility in
determining that BART is SNCR for Units 1 and 2 of the Colstrip
facility in Montana. Failure to consider cumulative visibility impacts
discounts the very real effect of source-specific pollution on regional
haze and likewise the cumulative benefits of potential retrofits. EPA
cannot demonstrate that it has properly evaluated BART controls for
affected sources without producing and presenting such a cumulative
analysis.
Response: EPA notes that, in considering the visibility
improvements reflected in our revised modeling, EPA interprets the BART
Guidelines to require consideration of the visibility improvement from
BART applied to the entire BART-eligible source. The BART Guidelines
explain that, ``[i]f the
[[Page 5131]]
emissions from the list of emissions units at a stationary source
exceed a potential to emit of 250 tons per year for any visibility-
impairing pollutant, then that collection of emissions units is a BART-
eligible source.'' In other words, the BART-eligible source (the list
of BART emissions units at a source) is the collection of units for
which one must make a BART determination. The BART Guidelines state
``you must conduct a visibility improvement determination for the
source(s) as part of the BART determination.'' This requires
consideration of the visibility improvement from BART applied to the
BART-eligible source as a whole. We note, however, that while our
regulations require states and EPA to assess visibility improvement on
a source-wide basis, they provide flexibility to also consider unit-
specific visibility improvement in order to more fully inform the
reasonableness of a BART determination, but that does not replace the
consideration of visibility benefit from the source (facility) as a
whole.
In making the BART determinations in this final action we have
considered visibility improvements at the source, and then also at the
units that comprise the source. The approach that we used in our BART
decisions for Wyoming is consistent with the approach that we used for
Montana.
Comment: The commenter submitted results of back trajectory HYSPLIT
modeling showing that pollutants reaching certain Class I areas on the
high nitrate haze days did not originate from Laramie River Station.
The commenter concludes that this analysis confirms that reducing
NOX emissions from Laramie River would not improve
visibility at these Class I areas.
Response: We disagree with the comment that the HYSPLIT results
submitted by the commenter can be used to evaluate the contribution of
Laramie River to visibility impairment at Wind Cave National Park. The
commenter performed HYSPLIT back-trajectory modeling for 10 days with
high ammonium nitrate concentrations at Wind Cave National Park. The 10
days were selected from the period from 2001 to 2010, and only two of
these days occurred during 2001 to 2003 baseline period used for the
BART visibility modeling. These two days were February 24, 2001 and
February 14, 2003, when the observed ammonium nitrate at the IMPROVE
monitoring site at Wind Cave National Park was 41 and 33 inverse
Megameters (Mm-1), respectively. We note that there were many days
during the 2001 to 2003 period on which observed ammonium nitrate
levels at Wind Cave National Park were in the range from 10 to 30 Mm-
1,\133\ but the commenter did not submit HYSPLIT results for these
days.
---------------------------------------------------------------------------
\133\ Document with Wind Cave IMPROVE data, in the docket.
---------------------------------------------------------------------------
HYSPLIT is a trajectory model similar to CALPUFF in that both
models use modeled and observed wind field data to predict the
trajectory of pollutants transported from a source area to a receptor
location. There are differences in the formulation of the HYSPLIT and
CALPUFF models and differences in the meteorological data used as input
data for each model, so the predicted trajectory from each model may
vary somewhat as a result of these differences. The most notable
difference in the two models is that CALPUFF is designed to predict
both the trajectory and the chemical conversion of precursor emissions
to fine particulates and to estimate the concentrations of ammonium
nitrate and other species at receptor sites, while HYSPLIT simply
predicts the trajectory of the emissions but does not predict the
chemical transformations nor the concentration of ammonium nitrate at
receptor sites.
We evaluated the CALPUFF results for February 24, 2001 and February
14, 2003, and found that the HYSPLIT and CALPUFF results were
consistent, i.e., the CALPUFF model did not attribute high levels of
ammonium nitrate at Wind Cave National Park on these two days to
Laramie River. The table of CALPUFF modeling results \134\ shows that
the model predicted a contribution of nitrate from Laramie River of
0.02 deciview on Feb 24, 2001, or 0.05% of the observed value, and on
Feb 14, 2003, 1.697 deciview, or 5% of the observed. The small modeled
contribution on these days is consistent with uncertainty in the
HYSPLIT model. Because the HYSPLIT model does not estimate the
formation of ammonium nitrate, and because HYSPLIT results were only
submitted for two days during the 2001 to 2003 baseline modeling
period, these HYSPLIT results are neither useful nor reliable for
identifying emissions sources that contribute to visibility impairment
at Wind Cave National Park. The HYSPLIT and CALPUFF results do indicate
that sources other than Laramie River contribute to visibility
impairment on the two days with the very highest ammonium nitrate
levels at Wind Cave during the 2001 to 2003 baseline period. However,
the CALPUFF results indicate that Laramie River contributes to
visibility impairment at Wind Cave National Park.
---------------------------------------------------------------------------
\134\ EPA CALPUFF modeling results for Laramie Rivers Station,
in docket: CALPUFF--WY--BART--bextNO3--BE--LR--Baseline--WindCave--
12112013.
---------------------------------------------------------------------------
Comment: EPA improperly considered ``cumulative visibility
improvement'' when it rejected Wyoming's BART NOX analyses
and required SCR at Naughton Unit 1 and Naughton Unit 2. (78 FR 34782).
Other comments asserted that EPA improperly considered ``cumulative
visibility improvement'' when it rejected Wyoming's BART NOX
analyses and required SCR at Dave Johnston Unit 3 (78 FR 34778).
Finally, a third set of comments asserted that EPA R8 has incorrectly
estimated visibility improvement from all NOX control
options at Wyodak: Wyoming DEQ evaluated cumulative visibility
improvements at the two nearest Class I areas (Wind Cave and Badlands
National Parks) while EPA R8 reported results for only one Class I
area.
Response: We disagree with these comments. In evaluating the
visibility improvement associated with various control options, EPA
interprets the CAA to require consideration of visibility improvement
at all impacted Class I areas. Consideration of improvement at multiple
Class I areas, as opposed to just benefits at the most impacted Class I
area, has often been described as ``cumulative visibility
improvement.'' Despite this terminology, however, an analysis of
cumulative visibility improvement does not necessarily require that the
deciview improvement at each area be summed together. While states or
EPA are free to take such a quantitative approach, they are also free
to use a more qualitative approach. Here, we chose to rely primarily on
the visibility improvement at the most impacted Class I area, while
also considering the number of additional Class I areas that would see
improvement, as well as the level of improvement at each area. We did
not expressly rely on a summation of visibility benefits across Class I
areas, as we have done in other regional haze actions, although this
metric was included in some tables. Finally, in our analysis of
visibility impacts, we considered the visibility improvement at both
Class I areas within 300 kilometers of Wyodak. The modeling results for
the second proposal for all Class I areas considered for each BART
source were available to the public during the comment period upon
request. (See ``Summary of EPA's Additional Visibility Improvement
Modeling'').
[[Page 5132]]
C. Overarching Comments on BART
1. BART-Eligible Sources
Comment: OCI Wyoming commented that it was listed as a BART-
eligible source, but that the facility has an enforceable cumulative
annual NOX emission limit of 175.2 tons/year. Therefore, the
facility is not a ``major stationary source'' and is not BART-eligible.
Response: We agree with this comment and acknowledge that OCI
Wyoming is not a BART-eligible source.
2. Costs of Controls
Comment: One commenter stated that it supported EPA's use of the
CCM and the Integrated Planning Model (IPM) to calculate costs.
Response: It is noted that EPA has revised the cost estimates found
in the proposed rule based upon input from various commenters. The
differences in cost for individual units may result from: (1)
Accounting for site elevation in the SCR capital cost; (2) Change in
SCR reagent to anhydrous ammonia from urea; (3) Change in urea SNCR
chemical utilization for Laramie River units due to high furnace
temperature; (4) Incorporation of some of the costs provided in
comments; (4) Change in auxiliary electrical cost from market price to
generating, or ``busbar,'' cost; (5) Correction of dilution water cost
equation for SNCR; and (6) Consideration of shorter plant lifetimes in
some instances.
More detailed descriptions of these changes and how they were
addressed are discussed in a report (Andover Report) and spreadsheets
\135\ developed for EPA's responses to comments, as well as in our
responses to the specific comments that are associated with these
changes below.
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\135\ Andover Technology Partners, ``Cost of NOX
Controls on Wyoming EGUs'', October 28, 2013; Wyoming EGU BART and
Reasonable Progress Costs--10/28/2013; Wyoming EGU BART and
Reasonable Progress Costs for Jim Bridger--10/28/2013.
---------------------------------------------------------------------------
Comment: Sargent & Lundy's analysis provides realistic information
regarding what it likely would cost to install and operate an SCR
system at Laramie River Station. They include a cost analysis by
Sargent & Lundy that, unlike EPA's consultant's work, follows the BART
Guidelines and EPA's CCM, and takes into account key site-specific
conditions at Laramie River Station. This analysis is far more accurate
and reliable than what was done by EPA's consultant--it is a site-
specific, from-the-ground-up analysis done by an engineering firm that
has done more NOX control projects for EGUs than any other
firm in the U.S. Sargent & Lundy's analysis provides realistic
information regarding what it likely would cost to install and operate
an SCR system at Laramie River. This analysis strongly supports
Wyoming's decision to select new LNBs and OFA as BART for Laramie River
Station, not SNCR or SCR.
Response: We do not agree with this comment. The BART Guidelines
provide that: ``You should include documentation for any additional
information used for the cost calculations, including any information
supplied by vendors that affects your assumptions regarding purchased
equipment costs, equipment life, replacement of major components, labor
productivity and rates and any other element of the calculation that
differs from the Control Cost Manual.'' 40 CFR part 51, app. Y, at
IV.4.a.
Thus, detailed cost documentation is necessary to the extent that
cost assumptions differ from the CCM. In this case, several of Sargent
& Lundy's cost assumptions for control costs at Basin Electric's
Laramie River Station differed from the CCM, but the necessary
supporting documentation was not provided as part of their report.
Detailed descriptions of the deficiencies in the cost assumptions are
described in comments specific to the units. As explained elsewhere in
this document, EPA has accepted some of the revised costs developed for
Basin Electric, but not others.
Comment: We found that EPA's consultant had added 1.2% to the total
capital investment of SCR to account for ``taxes and insurance.'' The
CCM says: ``In many cases property taxes do not apply to capital
improvements such as air pollution control equipment, therefore, for
this analysis, taxes are assumed to be zero. The cost of overhead for
an SCR system is also considered to be zero. An SCR system is not
viewed as risk-increasing hardware (e.g., a high energy device such as
a boiler or a turbine). Consequently, insurance on an SCR system is on
the order of a few pennies per thousand dollars annually.'' The BART
submittal by PacifiCorp included a 1.1% sales tax and Basin Electric
included a 4% sales tax, both of which were applied to the purchased
equipment costs. It is unclear if application of a sales tax is
appropriate in Wyoming and, if so, what the correct tax rate is.
Response: To the extent that sales or property taxes are actually
incurred and increase the cost of the project, they should be accounted
for in the cost. See CCM at 2.5.4.1 and 2.5.5.8. However, air pollution
control improvements often do not result in increased property taxes.
When these taxes are not in fact applied, they should not be included
in the estimate. The use of 1.2% as an estimate of property taxes and
insurance is a conservative estimate that is consistent with EPA's
assumptions in the IPM documentation. According to the IPM
documentation (version 4.10, Chapter 8, page 8-11): ``U.S. state
property taxes are approximately 0.9% based on a national average
basis. This is based on extensive primary and secondary research
conducted by ICF using property tax rates obtained from various state
agencies. . . . Insurance costs are approximately 0.3%. This is based
on estimates of insurance costs on a national average basis.'' \136\
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\136\ https://www.epa.gov/airmarkets/progsregs/epa-ipm/BaseCasev410.html#documentation.
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As noted by the commenter, these costs may not in fact apply for
environmental upgrades or may be much less than estimated. EPA did not
have information on the applicability of property taxes at the time we
conducted our cost estimates and conservatively assumed a reasonable
amount. We also note that the commenter did not provide sufficient
information to support a different property tax or insurance rate.
With regard to sales tax, the IPM algorithm for SCR cost is based
upon historical projects and incorporates typical levels of sales tax.
That is, the capital costs provided by the algorithm(s) are inclusive
of sales tax. Accordingly, for the purpose of the BART cost estimates,
and without additional data to determine what sales taxes would
actually apply, EPA has relied on the assumptions in the IPM algorithm.
Comment: EPA states in its FIP Action (78 FR 34749): ``For all
control technologies, EPA has identified instances in which Wyoming's
source-based cost analyses did not follow the methods set forth in the
EPA Control Cost Manual. For example, Wyoming included an allowance for
funds used during construction and for owners costs and did not provide
sufficient documentation such as vendor estimates or bids.''
With respect to AFUDC, another utility (Oklahoma Gas and Electric)
argued in a similar regional haze setting that: ``AFUDC provides a way
of measuring the real cost of interest over the construction period.
AFUDC accounts for the time value of money associated with the
distribution of construction cash flows over the construction period,
which may be approximately 18 months for an SCR project.'' Total
capital investment, as
[[Page 5133]]
defined in the CCM, includes all costs required to purchase equipment
needed for the control system (purchased equipment costs), the costs of
labor and materials for installing that equipment (direct installation
costs), costs for site preparation and building, working capital, and
off-site facilities.
A cost breakdown of total capital investment (as defined above) is
presented in several examples in the CCM. For example, Table 1.4 (page
1-32 of Section 4--NOX Controls) and Table 2.5 (page 2-44 of
Section 4--NOX Controls) therein explicitly identify AFUDC
as component ``E'' of the TCI, where TCI = D + E + F + G + H + I,
where: D = Total Plant Cost; E = AFUDC; F = Royalty Allowance; G =
Preproduction Cost; H = Inventory Capital; I = Initial Catalyst and
Chemicals.
References 9 and 10 on page 2-38 of the CCM explicitly include
AFUDC as a cost component and reference two reports, by Shattuck and
Kaplan, in support of its use. The EPA built upon this knowledge base
and costing methodology in its publication of the CCM in 2002. Thus,
the CCM allows the time value of money, measured by the real discount
rate, to be incorporated into the cost estimate.
Section 2.3.1 of the CCM (Elements of Total Capital Investment)
describes the need for total capital investment to include all
expenditures incurred during the construction phase of the project,
including direct costs, indirect costs, fuel and consumables expended
during start-up and testing, and other capitalized expenses. The only
items explicitly mentioned to be excluded are common facilities that
already exist at the site. AFUDC is part of the expense that will be
incurred with the installation of a large air pollution control system,
and the accepted practice in the utility industry and by financial
institutions is to treat AFUDC as a capitalized expenditure. This
approach is recognized in publications by the U.S. Department of
Energy--Energy Information Administration, such as the Annual Energy
Outlook, and in publications by the Electric Power Research Institute,
such as the Technical Assessment Guide (EPRI TAG). As previously
mentioned, the EPA clearly followed this approach in its studies of
retrofit costs of SO2 and NOX in the years
leading up to its publication of the CCM. Furthermore, AFUDC has been
included in several other coal-fired boiler BART determinations, and
AFUDC is included as a line item in EPA's Coal Quality Environmental
Cost (CUECost) worksheets for flue gas desulfurization (FGD) control
systems. In cases where the time value of money during the construction
period would be significant (e.g., projects with longer construction
periods such as the installation of SCR), the CCM clearly allows
inclusion of AFUDC.
PacifiCorp supports and adopts by reference Oklahoma Gas and
Electric's argument regarding including AFUDC in project cost
estimates. Whether or not AFUDC is included in project cost estimates
does not materially impact the results reached under the EPA CCM
method, its inclusion should not constitute a basis for EPA to reject
Wyoming's entire cost assessments. PacifiCorp has provided tables that
provide comparisons of PacifiCorp's project specific EPA CCM method
results where AFUDC is excluded in one set of costs and is included in
the other to demonstrate this point.
Response: We disagree with commenters' assertions that AFUDC is a
cost that should be incorporated into our cost analysis, as it is
inconsistent with CCM methodology. The utility industry uses a method
known as ``levelized costing'' to conduct its internal comparisons,
which is different from the methods specified by the CCM. Utilities use
``levelized costing'' to allow them to recover project costs over a
period of several years and, as a result, realize a reasonable return
on their investment. The CCM uses an approach sometimes referred to as
overnight costing, which treats the costs of a project as if the
project were completed ``overnight'', with no construction period and
no interest accrual. Since assets under construction do not provide
service to current customers, utilities cannot charge the interest and
allowed return on equity associated with these assets to customers
while under construction. Under the ``levelized costing'' methodology,
AFUDC capitalizes the interest and return on equity that would accrue
over the construction period and adds them to the rate base when
construction is completed and the assets are used. Although it is
included in capital costs, AFUDC primarily represents a tool for
utilities to capture their cost of borrowing and return on equity
during construction periods. AFUDC is not allowed as a capitalized cost
associated with a pollution control device under CCM's overnight
costing methodology, and is specifically disallowed for SCRs (i.e., set
to zero) in the CCM.\137\ Therefore, in reviewing other BART
determinations, EPA has consistently excluded AFUDC.\138\ EPA's
position regarding exclusion has been upheld in the United States Tenth
Circuit Court of Appeals.\139\
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\137\ CCM (Tables 1.4 and 2.5 show AFUDC value as zero).
\138\ See, e.g., 77 FR 20894, 20916-17 (Apr. 6, 2012)
(explaining in support of the North Dakota Regional Haze FIP, ``we
maintain that following the overnight method ensures equitable BART
determinations * * *.''); 76 FR 52388, 52399-52400 (August 22, 2011)
(explaining in the New Mexico Regional Haze FIP that the Manual does
not allow AFUDC)
\139\ Oklahoma v. U.S. EPA, 723 F.3d 1201 (10th Cir. 2013).
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The fact that CUECost, the EPRI TAG, and the Department of Energy
cost estimates, and even cost estimates used as the basis for IPM
typically include AFUDC is immaterial in this case because, for this
purpose, overnight cost methodology is used and AFUDC is not included
in that methodology.
Finally, we reject the commenter's assertion that Wyoming's
inclusion of AFUDC did not provide a material basis for EPA to
disapprove portions of the State's SIP. Inclusion of AFUDC increases
total project costs of SCR by several million dollars. For example,
Attachment 4 to PacifiCorp's comment letter shows that AFUDC for Dave
Johnston Unit 4 would add more than $9.5 million dollars to the capital
costs of SCR. We find that amounts of this magnitude are not trivial
when assessing the costs of compliance.
Comment: Sargent & Lundy's cost estimate does include AFUDC, which
accounts for the interest charges that would be incurred by Basin
Electric during SCR construction. AFUDC is a real and a significant
cost on capital intensive, long-term projects such as SCR installation,
which require financing over a construction period of up to four years.
Indeed, to exclude AFUDC would inappropriately bias the cost estimate
in favor of high capital intensity projects. Therefore, consistent with
industry practice, Sargent & Lundy included AFUDC, calculated based on
a typical SCR construction project cash flow assuming a real interest
rate of 7%.
The inclusion of AFUDC is not, as EPA asserts, inconsistent with
either the BART Guidelines or the CCM. See 78 FR 34749. The CCM simply
references ``Total Capital Investment,'' which includes ``all costs
required to purchase equipment needed for the control system,'' as well
as ``working capital.'' CCM 2.3.1, page 2-5 (emphasis added). This
includes costs required to purchase equipment needed for the control
system (purchased equipment costs), the costs of labor and materials
for installing that equipment (direct installation costs), costs for
site preparation and building, working
[[Page 5134]]
capital, and off-site facilities. Id. Nowhere in the CCM does EPA state
that AFUDC is not an appropriate cost, particularly with respect to
long-term, capital intensive pollution control projects. And even if
the CCM made such an assertion, inclusion of AFUDC in a cost estimate
cannot be grounds for SIP disapproval because: (1) the CCM is not
binding for purposes of making BART determinations, and (2) requiring
states to exclude AFUDC is not consistent with Congress' general
directive that states include ``costs of compliance'' in their BART
determinations.
The CAA requires states to consider in their BART determinations
the ``costs of compliance,'' but does not further define the term. See
42 U.S.C. 7491. EPA's regulations codify the BART factors, but neither
the regulations nor the BART Guidelines in Appendix Y purport to
restrict in any manner the categories of costs that states should
consider when making a BART determination. See 70 FR 39166-39168. AFUDC
is a ``cost of compliance.'' Basin Electric cannot fund large capital-
intensive projects like SCR without financing, and the costs related to
such financing are real and substantial. Consideration of AFUDC is
therefore entirely consistent with the CAA's broad reference to ``costs
of compliance,'' and excluding AFUDC would be inconsistent.
In this case, even if AFUDC is excluded from the total annual
costs, the costs of installing SCR do not decrease substantially enough
to justify SCR. Sargent & Lundy performed sensitivity analyses
demonstrating that the cost-effectiveness of SCR at Laramie River
remains at between $8,531 per ton of NOX removed and $9,048
per ton of NOX removed even if AFUDC is excluded.
Furthermore, if the maintenance cost and labor rate of 1.5% also is
factored into the analysis, consistent with the CCM, as opposed to the
lower 0.25% used by Sargent & Lundy, the cost-effectiveness remains
above $8,500 per ton of NOX removed. Sargent & Lundy also
performed a sensitivity analysis demonstrating that including property
taxes and insurance as 1.2% of total capital investment, consistent
with the approach taken by Andover but not with the CCM approach, more
than offsets the exclusion of AFUDC. S&L Evaluation section 7.1.4,
Table 10.
Response: EPA agrees that AFUDC can be a substantial overall cost
on large capital projects that extend over a period of several years.
However, as noted in the previous response, the CCM clearly excludes
AFUDC in the overnight cost method. Furthermore, as we explain in more
detail in responses to comments that pertain to specific sources, we
disagree with the commenter's estimates for cost effectiveness for the
Laramie River units.
Comment: Commenters assert that EPA's regional haze FIP is flawed
because it failed to provide sufficient documentation, such as vendor
estimates or bids to validate its estimates. EPA attempts to justify
its approach by stating: ``In our revised cost analyses, we have
followed the structure (emphasis added) of the EPA CCM, though we have
largely used the Integrated Planning Model cost calculations to
estimate direct capital costs and operating and maintenance costs.'' 78
FR 34749.
EPA did not explain what it meant by following the ``structure'' of
the manual, versus simply following the manual. By contrast, PacifiCorp
solicited and incorporated vendor estimates into these comments. This
new information, which EPA must incorporate into new BART analyses to
the extent EPA issues a final regional haze FIP, validates Wyoming's
BART analyses cost of control estimates. In addition, it further
quantifies the inaccuracies in EPA's development and use of purported
new information that in no way qualifies as vendor estimates, bids, or
any type of site-specific vendor information.
Response: We do not agree with this comment. By following the
``structure'' of the manual, EPA included all of the cost elements that
the CCM indicates should be included, while excluding those that should
not (such as AFUDC). In other words, EPA employed the overnight cost
method as is required for BART analyses. The BART Guidelines require
that the CCM be followed unless deviations from it are clearly
documented and explained.
PacifiCorp received bids from vendors and EPA has incorporated
information from these bids into its revised cost estimates. However,
for reasons described elsewhere in response to comments, EPA has not
accepted all of the costs. The BART Guidelines state: ``You should
include documentation for any additional information you used for the
cost calculations, including any information supplied by vendors that
affects your assumptions regarding purchased equipment costs, equipment
life, replacement of major components, and any other element of the
calculation that differs from the CCM.'' 70 FR 39166.
With regard to Basin Electric, vendor quotes for the Laramie River
Station were not supplied. As Basin Electric indicated in its comments,
``[t]he LRS cost estimates are conceptual in nature; thus, S&L did not
procure equipment quotes specifically for the LRS control systems.
Rather, equipment costs for the LRS projects are based on conceptual
designs developed for the control systems, preliminary equipment sizing
developed for the major pieces of equipment, and recent pricing for
similar equipment.''
In effect, like the IPM cost algorithms, the method that underlies
Sargent & Lundy's estimate for Basin Electric is empirically based on
past data, and not vendor quotes developed specific to Laramie River.
We have, however, accepted some of the costs submitted by Basin
Electric and not accepted others.
Comment: Even if EPA had the authority to require the use of the
CCM, which it does not, EPA's insistence on Wyoming's strict compliance
with the costing methodology set forth in the CCM, without adjusting
the methodology to account for important site-specific factors, leads
to an erroneous and arbitrary and capricious result. This is not
required by the CCM. Indeed, the manual expressly discounts the
usefulness of the costing methodology to power plants generally and to
SCR control systems specifically, and it acknowledges that deviation
from the methodology may be appropriate based on a user's engineering
judgment.
The CCM provides general costing methodology for stationary source
air pollution control technologies, applicable primarily to regulatory
development where a rough order of magnitude estimate is appropriate.
The introduction to the manual also caveats its usefulness when
assessing control costs at power plants, which use different cost
accounting. Cost Manual section 1.1, page 1-3. Specifically, it states
that ``[e]lectrical utilities generally employ the EPRI Technical
Assistance Guidance (TAG) as the basis for their cost estimation
processes.'' Id. In a footnote, it explains that while power plants
might still use the manual, ``comparisons between utilities and across
the industry generally employ a process called `levelized costing' that
is different from the methodology used here.'' Id. section 1.1, page 1-
3 n.1.
The CCM also generates rough estimates of costs that are less
accurate than the site-specific cost factors that are more appropriate
for BART determinations at a large power plant. The manual is used
heavily in regulatory development, and the costing methodology is
geared specifically to avoid the necessity of site-specific information
and to enable estimates to be prepared at ``relatively low cost with
[[Page 5135]]
minimum data.'' Id. section 2.2, page 2-3 (internal quotations
omitted). However, the level of accuracy is much lower than that for
estimates using site-specific information. The cost estimating
procedure can provide a ``rough order of magnitude,'' estimate that is
``nominally accurate to within 30%.'' Id. section 1.2,
page 1-4. Indeed, ``EPA does not claim cost estimates for industry at a
greater than study level accuracy for industrial users'' because ``the
industrial user will necessarily have much more detailed information
than the generic cost and sizing information.'' Id. section 2.2, page
2-3, 2-4.
Where the user has detailed site-specific information, the manual
does not contemplate strict adherence to its costing methodology. Users
may ``exercise `engineering judgment' on those occasions when the
procedures may need to be modified or disregarded.'' Id. section 1.3,
page 1-7. With respect to estimating factors used in cost estimates,
``the application of an appropriate factor requires the subjective
application of the analyst's best judgment.'' Id. section 2.5.4.1, page
2-28. The manual is designed to provide a tool box for estimating costs
that can be helpful to the engineer, but ``[t]he bottom line is that
there is no clear-cut `cookbook' process through which the analyst will
be able to make the right informed decision each time, and the
formalized costing methodology employed by the Manual is only part of
that process.'' Id. section 2.6, page 2-37.
With respect to SCR cost estimations, the CCM is no more than a
``tool to estimate study-level costs for high-dust SCR systems.'' Id.
section 2.4, page 2-40. The ``[a]ctual selection of the most cost-
effective option should be based on a detailed engineering study and
cost quotations from the system suppliers.'' Id. This requirement for a
more detailed study relying on site-specific factors is necessary
because, as EPA acknowledges, the CCM's assumptions regarding capital
investment for SCR are inaccurate. Id. section 2.5.4.1, page 2-27. For
systems like SCR, ``the control in question is either so large or so
site-specific in design that suppliers design, fabricate, and construct
each control according to the specific needs of the facility.'' Id.
section 2.5.4.1, page 2-27.
Thus, for these systems, ``the Manual deviates from its standard
approach of providing study level costs and, instead, provides a
detailed description of the factors that influence the TCI [total
capital investment] for the analyst to consider when dealing with a
vendor quotation.'' Id. Under these circumstances, EPA acknowledges
that getting vendor quotes may be difficult because they cannot be done
in an ``off-the-shelf'' fashion. Id. The engineering judgment of the
manual's user is especially critical in estimating the costs of an SCR
retrofit: ``Probably the most subjective part of the cost estimate
occurs when the control system is to be installed on an existing
facility.'' Unless the original designers had the foresight to include
additional floor space and room between components for new equipment,
the installation of retrofitted pollution control devices can impose an
additional expense to ``shoe-horn'' the equipment into the right
locations. For example, an SCR reactor can occupy tens of thousands of
square feet and must be installed directly behind a boiler's combustion
chamber to offer the best environment for NOX removal. For
these boilers, there is generally little room for the reactor to fit in
the existing space and additional ductwork, fans, and flue gas heaters
may be needed to make the system work properly.
To quantify the unanticipated additional costs of installation not
directly related to the capital costs of the controls themselves,
engineers and cost analysts typically multiply the cost of the system
by a retrofit factor. The proper application of a retrofit factor is as
much an art as it is a science, in that it requires a good deal of
insight, experience, and intuition on the part of the analyst. The key
behind a good cost estimate using a retrofit factor is to make the
factor no larger than is necessary to cover the occurrence of
unexpected (but reasonable) costs for demolition and installation. Such
unexpected costs include, but are certainly not limited to, the
unexpected magnitude of anticipated cost elements; the costs of
unexpected delays; the cost of reengineering and re-fabrication; and
the cost of correcting design errors. Id. section 2.5.4.2, page 2-28.
The CCM cannot properly account for these uncertainties and thus
provides that users can apply a ``retrofit factor'' of up to 50 percent
to account for them. Id. EPA notes that ``[s]ince each retrofit
installation is unique, no general factors can be developed.'' Id.
2.5.4.2, page 2-29.
In sum, the BART Guidelines and CCM were drafted and are to be
applied as guidelines to assist the states in their decision making,
not as inflexible mandates. Knowing this, states like Wyoming follow
the BART Guidelines generally but make the necessary localized and
individualized adjustments required to generate realistic, rather than
formalistic, cost estimates. Accordingly, EPA should expect the states
to deviate on occasion, not to slavishly follow the BART Guidelines and
CCM to the point of generating artificial (and unrealistic) cost
estimates. Yet that is now exactly what EPA contends the states must
do. EPA's current approach to using the BART Guidelines and manual as
grounds for disapproval without deference to the states' authority and
local control is unreasonable, erroneous, and arbitrary and capricious.
Response: There are only very limited situations in which a state
or EPA can depart from the CCM cost methodology. ``The basis for
equipment cost estimates also should be documented, either with data
supplied by an equipment vendor (i.e., budget estimates or bids) or by
a referenced source (such as the OAQPS CCM, Fifth Edition, February
1996, EPA 453/B-96-001). In order to maintain and improve consistency,
cost estimates should be based on the OAQPS CCM, where possible. The
CCM addresses most control technologies in sufficient detail for a BART
analysis. The cost analysis should also take into account any site-
specific design or other conditions identified above that affect the
cost.'' 70 FR 39166.
The guidelines for BART determinations make it clear that the CCM
is the intended methodology for conducting a BART cost determination.
It also states why: To maintain and improve consistency. However, the
CCM does state that site-specific conditions should be incorporated.
Site-specific conditions could include space constraints, or a design
feature that could complicate installing a control. However, the BART
Guidelines are clear that the analyst should document any deviations
from the CCM: ``You should include documentation for any additional
information you used for the cost calculations, including any
information supplied by vendors that affects your assumptions regarding
purchased equipment costs, equipment life, replacement of major
components, and any other element of the calculation that differs from
the CCM.'' 70 FR 39166.
In fact, the record does not point to any unusual circumstances
that explain why SCR costs in Wyoming should be so much higher than
costs of SCR at other similar facilities. As will be demonstrated in
responses to comments that are specific to the individual units, the
commenters did not identify any unique features of their plants that
would make of the installation of an SCR so difficult that the cost
would be outside the range of what has been experienced elsewhere, even
accounting for such things as elevation, which is discussed later in
these responses to
[[Page 5136]]
comments. The BART Guidelines also provide the following explanation,
which makes it clear that other cost methods are supplemental, not
replacements for the CCM cost method: ``We believe that the CCM
provides a good reference tool for cost calculations, but if there are
elements or sources that are not addressed by the CCM or there are
additional cost methods that could be used, we believe that these could
serve as useful supplemental information.'' 70 FR 39127.
Although the focus in the second quote is ensuring the remaining
useful life is incorporated into the amortization schedule, this
passage affirms that the CCM's annualized cost methodology should be
followed. The following quote from the same page of the BART guidelines
sheds light on the type of costing methodology employed by the CCM,
``capital and other construction costs incurred before controls are put
in place can be rolled into the first year, as suggested in EPA's OAQPS
CCM.'' Although this passage is again focused on the remaining useful
life, the text we reproduce is a reference to the basic CCM cost
methodology--the overnight method. That is what is meant with the
reference of rolling future costs into the first year. The ``all in''
method that OG&E used does not do that--it projects costs to a future
date. Although the CCM does not use the term, ``overnight cost,'' it is
widely used in industry.
The U.S. Energy Information Administration defines ``overnight
cost'' as ``an estimate of the cost at which a plant could be
constructed assuming that the entire process from planning through
completion could be accomplished in a single day. This concept is
useful to avoid any impact of financing issues and assumptions on
estimated costs.'' \140\ In effect, the overnight cost is the present
value cost that would have to be paid as a lump sum up front to
completely pay for a construction project.
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\140\ EIA, ``Updated Capital Cost Estimates for Electricity
Generation Plants,'' November 2010, footnote. 2. Available at:
https://www.eia.gov/oiaf/beck_plantcosts/?src=email.
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As will be described in EPA's other responses to comments regarding
specific plants, commenters did not provide the documentation required
under the RHR to demonstrate why their costs were so much higher than
costs for other similar units. Such documentation would include any
vendor quotes to include scope of supply, explanations of labor
productivity issues with supporting documentation, and other concerns
raised by commenters and addressed in more detail in other comments.
Comment: Sargent & Lundy is both a design and engineering firm and
a system supplier, and it has provided exactly the type of detailed
scoping-level engineering study for SCR contemplated by the CCM when
selecting the most cost-effective NOX control device. EPA
acknowledges that with respect to SCR cost estimations, the CCM is no
more than a ``tool to estimate study-level costs for high-dust SCR
systems.'' CCM section 2.4, page 2-40. For systems such as SCR, ``the
control in question is either so large or so site-specific in design
that suppliers design, fabricate, and construct each control according
to the specific needs of the facility.'' Id. section 2.5.4.1, page 2-
27. See also id. at section 2.3, page 2-30 (``the design is highly
site-specific.''). Importantly, the ``[a]ctual selection of the most
cost-effective option should be based on a detailed engineering study
and cost quotations from the system suppliers.'' Id. at section 2.6,
page 2-43.
The Sargent & Lundy Evaluation provides a cost estimate not based
on the general, broad brush assumptions set forth as examples in the
CCM, but on a conceptual design of SCR at Laramie River based on site-
specific variables and Sargent & Lundy's extensive knowledge of, and
experience with, SCR installations on coal-fired utility boilers. Based
on this conceptual design, Sargent & Lundy estimated equipment costs
using example vendor quotes for similar projects, and used appropriate
commodity pricing references, rates for labor based on industry
publications and locality-specific data, and, where necessary,
allowances.
Response: As EPA has noted in previous responses to comments, the
CCM is a good reference tool for estimating costs. With regard to
Sargent & Lundy's estimates at Laramie River Station, EPA has found
deficiencies in the cost estimates or underlying assumptions that will
be discussed in more detail in comments that are specific to units.
Comment: One commenter asserted that the EPA's cost evaluations
overestimated the annualized capital costs of BART options by assuming
an unrealistically high interest rate, which is particularly extreme in
the cost estimates for SCR because of its relatively higher capital
costs than the other control technologies evaluated. The commenter
calculated and submitted documentation of what the commenter considers
to be the real cost of capital interest to PacifiCorp, which was 5.66
percent, and to Basin Electric, which was around 2 percent. According
to the commenter, the EPA continues to assume a much higher 7 percent
interest rate, apparently based on the EPA's mistaken belief that this
rate is supported by the CCM. The commenter stated that while the CCM
states the social interest rate ``is currently set at seven percent''
by the Office of Management and Budget (OMB), it references the
interest rate established by OMB in 1992, whereas the OMB updates
interest rates yearly and the current social interest rate is 1.7
percent for a 20-year period (citing OMB Circular A-94, App. C (revised
Dec. 2012)).\141\ The commenter concluded that even if EPA were correct
in applying the social interest rate, it should have used the current
published OMB rate in accordance with the CCM's direction.
---------------------------------------------------------------------------
\141\ https://www.whitehouse.gov/sites/default/files/omb/assets/a94/dischist-2013.pdf.
---------------------------------------------------------------------------
The commenter went on to contend that the CCM recommends a source-
specific interest rate for BART and reasonable progress determinations,
rather than the social interest rate applied in promulgation of
regulations. According to the commenter, the 7-percent ``social
interest rate'' is used to estimate the cost to society of taking an
action. However, the CCM states that this social interest rate ``is
probably not appropriate for industry.'' The commenter noted that the
RHR requires the EPA to make case-by-case determinations of ``the costs
of compliance'' for identified BART and reasonable progress options,
which the commenter interprets as being the actual cost to the source
of implementing the studied alternatives. The commenter indicated that
where the EPA, the state, or industry is evaluating ``the economic
impact that [air-pollution control] equipment would have upon the
source,'' a source-specific interest rate is appropriate. The commenter
concluded that the EPA erred in relying on a generic and outdated 7-
percent social interest rate that resulted in a particularly inflated
estimate of SCR costs, and asserted that in recalculating the
annualized capital costs of control technologies, the EPA must either
use the current social interest rate of 1.7 percent, or more
appropriately, source-specific rates of 5.66 percent for PacifiCorp
Units and 2 percent for Basin Electric Units.
Response: We have retained the use of a 7-percent interest rate in
calculating the capital recovery factor. For cost analyses related to
government regulations, an appropriate ``social'' interest (discount)
rate should be used,
[[Page 5137]]
not the source's actual rate of borrowing. OMB Circular A-4, providing
Federal agencies guidance on developing regulatory analyses, and dated
September 17, 2003, reiterates the guidance found in the earlier
Circular A-94: ``As a default position, OMB Circular A-94 states that a
real discount rate of 7 percent should be used as a base-case for
regulatory analysis. The 7 percent rate is an estimate of the average
before-tax rate of return to private capital in the U.S. economy, based
on historical data. It is a broad measure that reflects the returns to
real estate and small business capital as well as corporate capital. It
approximates the opportunity cost of capital, and it is the appropriate
discount rate whenever the main effect of a regulation is to displace
or alter the use of capital in the private sector.'' \142\
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\142\ Office of Management and Budget, Circular A-4, Regulatory
Analysis, https://www.whitehouse.gov/omb/circulars-a004_a_4/.
---------------------------------------------------------------------------
In addition, EPA calculated capital recovery factors using 3-
percent and 7-percent interest rates in determining cost-effectiveness
for the Regulatory Impact Analysis for the BART Guidelines.\143\ The 3-
percent rate is mainly used when private consumption displacement is
the main impact of a regulatory action. This cost of retrofitting power
plants for this action displaces private capital far more than private
consumption, so 3-percent is not an interest rate that is applicable
here. We consider our use of an interest rate of 7-percent to calculate
capital recovery to be a conservative approach.
---------------------------------------------------------------------------
\143\ ``Regulatory Impact Analysis for the Final Clean Air
Visibility Rule or the Guidelines for Best Available Retrofit
Technology (BART) Determinations Under the Regional Haze
Regulations,'' EPA-0452/R-05-004 (June 2005).
---------------------------------------------------------------------------
Finally, the interest rate cited by the commenter from Appendix C
to OMB Circular A-94, 1.7 percent, is for an altogether different
purpose than the type of regulatory analysis supporting today's rule.
According to the discount rate policy described in Circular A-94,
interest rates contained in Appendix C, which reflect Treasury
borrowing rates, are for the purpose of internal planning decisions of
the Federal Government. This is in contrast to regulatory actions, for
which as noted above, the circular prescribes use of a ``real discount
rate of 7 percent.'' \144\
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\144\ https://www.whitehouse.gov/omb/circulars_a094#8.
---------------------------------------------------------------------------
Comment: One commenter stated that the EPA used the IPM default
cost for auxiliary power of $0.06/kWhr for all of the control scenarios
evaluated, which is much higher than the auxiliary power cost commonly
used in cost-effectiveness analyses. The commenter asserted that the
appropriate cost of auxiliary power to use in a cost-effectiveness
analysis is the busbar cost of power to run the plant, not the cost of
power sold. According to the commenter, auxiliary power is the power
required to run the plant, or power not sold, and cost-effectiveness
analyses are based on the cost to the owner to generate electricity, or
the busbar cost, not market retail rates. The commenter indicated that
the site-specific data reported by PacifiCorp to the Federal Energy
Regulatory Commission (FERC) in 2010 indicates that the busbar power
cost for the Wyoming PacifiCorp plants is typically in the range of
$0.02/kWhr to $0.03 lb/kWhr, and for Basin Electric's Laramie River
Station, the company used a cost of $0.015/kWhr, which is consistent
with the busbar power cost.
Response: In EPA's original analysis, we used the default values
for electricity in the IPM model, although we agree that the cost of
power used for auxiliary loads should be the cost of the owner to
generate the electricity rather than the market price it could be sold
at. EPA has reviewed FERC Form 1 for PacifiCorp \145\ and has
incorporated in our revised costs for each plant the stated cost of
electricity per net kWh. For Laramie River Station, the costs in their
July 2008 BART analysis \146\ are used, as these are more consistent
with PacifiCorp's reported cost of generation (as reported to FERC)
than the values later used by Basin Electric or by EPA in our original
cost analysis (that our proposed action was based on), which are more
reflective of retail power prices rather than the cost to generate.
---------------------------------------------------------------------------
\145\ FERC Financial Report, FERC Form No. 1: ``Annual Report of
Major Electric Utilities, Licensees and Others and Supplemental Form
3Q: Quarterly Financial Report, PacifiCorp, Year/Period of Report
2010/Q4,'' pgs 402.2, 403, 403.2, see line 35.
\146\ Black & Veatch, ``Basin Electric Power Cooperative Laramie
River Station Refined BART Visibility Modeling,'' July 24, 2008, pg
25 of 176.
---------------------------------------------------------------------------
Comment: One commenter argued that the IPM model is not appropriate
for generating site-specific cost estimates to evaluate the cost-
effectiveness of BART projects because it does not account for those
site-specific requirements that significantly impact overall project
costs.
Response: As described in our proposal, the IPM is a multi-regional
linear programming model of the U.S. electric power sector. IPM relies
upon a very large number of data inputs and provides forecasts of
least-cost capacity expansion, electricity dispatch, and emission
control strategies for meeting energy demand and environmental,
transmission, dispatch, and reliability constraints. EPA has used IPM
to evaluate the cost and emissions impacts of proposed rules, such as
the recent Mercury and Air Toxics Standard (MATS).\147\
---------------------------------------------------------------------------
\147\ https://www.epa.gov/airmarket/progsregs/epa-ipm/docs/SuppDoc410MATS.pdf.
---------------------------------------------------------------------------
We wish to clarify that, for our proposed action on Wyoming's
Regional Haze SIP, we did not actually run IPM. Rather, we used
information from one component of IPM, specifically, the component that
develops the costs of air pollution control technologies. Broadly
speaking, IPM relies upon numerous components and sub-components to
specify constraints and variable values that feed into the model
algorithms used during an actual IPM model run. The air pollution
control cost development component is just one of these numerous
components. We relied upon the cost information and equations contained
in this component by manually placing them into a spreadsheet that
calculated the capital, operating, and maintenance costs associated
with pollution control options. While we relied upon the results of
these spreadsheet calculations, we did not then use those results to
run IPM, as the type of information generated by an actual IPM model
run (e.g., generation dispatch decisions, capacity decisions) is not
relevant to our action.
We documented our use of the equations from IPM's air pollution
control technology cost component by placing the raw cost calculation
spreadsheets in the docket for our proposal.\148\ These spreadsheets
contain the IPM equations, corresponding variable values, selected
notes regarding assumptions and variable ranges, as well as selected
tables from IPM Base Case v4.10 documentation. Because we did not
perform an actual IPM model run, the spreadsheet and contractor's
report in the docket for our proposal sufficiently document our use of
the cost methodologies from the IPM air pollution control cost
component.
---------------------------------------------------------------------------
\148\ Wyoming EGU BART and Reasonable Progress Costs--10/28/
2013; Wyoming EGU BART and Reasonable Progress Costs for Jim
Bridger--10/28/2013.
---------------------------------------------------------------------------
We disagree with commenters' characterization of the cost-
development methodology contained in IPM as generalized and inadequate
for performing site-specific cost estimates. As noted in the
documentation for IPM's cost-development methodology for SCR, the
methodology is based upon
[[Page 5138]]
two databases of actual SCR projects.\149\ These databases include 2004
and 2006 industry cost estimates prepared for the Midwestern Ozone
Group, and a proprietary in-house database maintained by engineering
firm Sargent & Lundy. The Midwestern Ozone Group information was cross-
referenced with actual 2009 projects, and escalated accordingly.
Sargent & Lundy then used the information in these databases to develop
the equations described in the cost component, taking into account the
pre-control NOX emission level, degree of reduction, coal
type, facility size, and numerous other unit-specific factors. While a
costly engineering evaluation that included site visits in addition to
use of satellite imagery might produce a more refined cost estimate, we
disagree that our approach does not produce site-specific estimates. As
noted by EPA in response to other comments, EPA's use of satellite
imagery enabled us to evaluate each of the major site-specific issues
raised by commenters.
---------------------------------------------------------------------------
\149\ https://www.epa.gov/airmarkets/progsregs/epa-ipm/docs/v410/Appendix52A.pdf.
---------------------------------------------------------------------------
Specifically, we input several site-specific factors, such as fuel
type, baseline NOX level, reagent cost and type, level of
NOX reduction, site-specific power and reagent costs, etc.
into the algorithm. The algorithm also provides for adjustment of cost
to account for retrofit difficulty. The CCM at section 2.5.4.2 (page 2-
28 of Section 1 Chapter 2) calls for a retrofit difficulty factor to
account for the site-specific costs associated with a retrofit, such as
demolition or moving existing equipment, etc. A retrofit factor is also
used in the IPM algorithm, making it consistent with the approach used
in the CCM. Per the documentation for the IPM algorithms: ``The
formulation of the SCR cost estimating model is based upon two
databases of actual SCR projects. The comparison between the two sets
of data was refined by fitting each data set with a least squares curve
to obtain an average $/kW project cost as a function of unit size. The
data set was then collectively used to generate an average least-
squares curve fit. The least squares curve fit was based upon an
average of the SCR retrofit projects. Retrofit difficulties associated
with an SCR may result in capital cost increases of 30 to 50 percent
over the base model. The least squares curve fits were based upon the
following assumptions: Retrofit Factor =1; Gross Heat Rate = 9880;
SO2 Rate = < 3 lb/MMBtu; Type of Coal = Bituminous; Project
Execution = Multiple lump sum contracts.'' \150\
---------------------------------------------------------------------------
\150\ Sargent & Lundy, ``IPM Model--Revisions to Cost and
Performance for APC Technologies--SCR Cost Development Methodology,
FINAL'', August 2010.
---------------------------------------------------------------------------
Therefore, the IPM algorithm is based upon actual retrofit
projects. As such, the average or typical retrofit found for the
retrofit projects evaluated is assumed to use a retrofit factor of 1.0,
and for more difficult than average retrofits, a retrofit factor
greater than 1.0 would apply. On page 1 of the documentation of the IPM
model for SCR, it states that ``Retrofit difficulties associated with
an SCR may result in capital cost increases of 30 to 50% over the base
model.'' Therefore, EPA expects that retrofit difficulty factors may
apply up to around 1.50 at the maximum. In effect, project elements
that are typically included in an SCR retrofit are accounted for in the
cost estimated by the algorithm, and deviations from those typical
costs can be addressed by a retrofit factor. In fact, the algorithm
expressly calls for a retrofit factor that can be varied (see Table 1
of reference, variable ``B''), which makes it consistent with the
retrofit difficulty factor method called for in the CCM. And, because
the IPM algorithm is based upon actual projects, it already
incorporates contingency. Finally, the IPM algorithm can be modified
for other effects, such as elevation, and EPA has since examined this
and modified its estimates in this final action to correct for the
effects of altitude.
Comment: One commenter alleged that site elevation was not
reasonably accounted for in EPA's cost estimates, particularly for
PacifiCorp's Naughton Units 1 and 2 and Dave Johnston Unit 3. The
commenter explained that algorithms in the IPM model were developed for
a generic coal-fired power plant located at or near sea level. However,
site elevation can have a significant impact on control system sizing
and design. Thus, elevation of the site must be considered separately
and factored into the unit capacity (i.e. megawatts) accordingly due to
its effects on the flue gas volume. The commenter pointed out that
PacifiCorp's Wyoming BART units are located at elevations ranging from
approximately 5,000 to 7,000 feet above mean sea level. At this
elevation, flue gas flows will be 20-30 percent higher than similarly
sized units at mean sea level. The higher flue gas flow requires larger
ductwork, larger reactors, and more robust support structures, and
these items have a profound influence on the overall project cost.
While Wyoming had this information available in its SIP, EPA failed to
account for site elevation in its FIP.
Response: EPA agrees with commenter that higher altitudes will
increase the volume of flue gas, making it necessary to increase the
cross-sectional area of associated ductwork and the SCR reactor.
Increased flue gas volume also impacts the fan design. Consequently,
EPA has revised its cost calculations for SCR in this final action to
address issues associated with plant altitude. While altitude has a
significant impact on the cost of SCR, it does not make a significant
difference in the cost of SNCR because altitude does not affect the
urea flow rate or the associated urea storage system, urea circulation
system, or metering/mixing/pumping systems. There may be a slight
increase in the number of injectors due to increased furnace cross-
section, but this is expected to be a small part of the total cost of
an SNCR system.
Comment: The same commenter argued that site configurations were
not reasonably accounted for in EPA's cost estimates, particularly for
the Naughton Units 1 and 2 and Dave Johnston Unit 3. The IPM model
applies a retrofit factor to account for the difficulty of fitting new
BART equipment into the existing site configuration. The Andover Report
states that site visits were not possible. Thus, retrofit factors for
Naughton Units 1 and 2, and Dave Johnston Unit 3 were determined based
on a review of Google EarthTM images of the station.
Accordingly, the Andover Report applied retrofit factors for the units
that are highly subjective based on minimal site information. The
commenter argued that, when preparing site-specific cost estimates,
site visits must be conducted to evaluate the true complexity
associated with the retrofit and to assess specific modifications to
the plant that would be required to overcome issues associated with
congestion, as well as difficulties associated with construction.
Neither Andover nor EPA sought permission from PacifiCorp to visit the
sites of the BART units, nor did Andover explain why it ``wasn't
possible'' to do so. Both Sargent & Lundy and Babcock and Wilcox have
extensive experience with PacifiCorp's Naughton and Dave Johnston
facilities. Just since 2005, Sargent & Lundy has been contracted by
PacifiCorp to perform 14 projects at Dave Johnston station and over 25
projects at Naughton station. These projects range from site
evaluations, studies, detailed engineering, or functioning as
PacifiCorp's Owner's Engineer for major environmental retrofit
engineer, procure, and construct projects. From having conducted many
site visits at these stations, Sargent &
[[Page 5139]]
Lundy is very aware of site-specific congestion and construction
challenges that would affect SCR installations at Naughton Units 1 and
2 and Dave Johnston Unit 3. Similar to Sargent & Lundy's site-specific
experience, Babcock and Wilcox has recently completed major
environmental retrofit projects on Naughton Units 1 and 2 (wet scrubber
additions) and Dave Johnston Unit 3 (dry scrubber and baghouse
addition), making Babcock and Wilcox uniquely positioned to offer
budgetary cost estimates for further retrofits to those facilities with
significant first-hand knowledge. While Wyoming had much of this
information available in its SIP, EPA failed to account for this site-
specific information in its FIP.
Response: EPA disagrees with the commenter. EPA did account for
site-specific factors when performing its cost estimates. Because SCRs
are built on or next to the boiler structure, they are often elevated,
and there is usually equipment in one direction (the boiler) or the
other (other air pollution control equipment, like an electrostatic
precipitator (ESP), scrubber, or chimney) that limits access. This
issue is complicated further with boilers that are located adjacent to
one another--a common configuration. Due to the height of the SCR,
large cranes play a vital role in their construction. The location of
cranes next to where the SCR is going to be built can be difficult.
As noted in a paper by Babcock & Wilcox,\151\ key issues for SCR
constructability are site access and ability to locate a crane and the
resulting erection sequence. The erection sequence is impacted by the
crane that is available and whether it can fit on site because the
crane and its location will limit the size of material that can be
lifted into place. A larger crane allows for the lifting of larger
pieces of ductwork, resulting in fewer lifts and less fabrication in
the air. Without adequate access for a crane and proximity to a lay-
down area for material, erection must be done with smaller pieces,
which will require more labor and expense.
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\151\ Hines, J.A., Kokkinos, A., Fedock, D., ``Benefits of SCR
Design for Constructability'', Power Gen, International 2001,
December 11-13, 2001, Las Vegas
---------------------------------------------------------------------------
Access around and between the boilers will determine crane location
and location of material receiving areas. In some cases, it may be
necessary to demolish equipment or buildings in order to gain adequate
access. In other cases, it may be necessary or preferable to erect
cranes on the top of the boiler structure (as was performed for the SCR
installed at Dominion's Brayton Point Unit 3).\152\
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\152\ Wright, B., Erickson, C., Phillipo, M., ``Keys to Success:
SCR Installations at Dominions Brayton Point Units 1 and 3'',
Electric Power, May 2008.
---------------------------------------------------------------------------
Because of its easy availability and it usefulness in providing a
``bird's eye'' view of the site congestion (how close equipment is
located to each other, room for a crane, etc.), site access, local
transportation options, availability of a lay-down area to locate
material on site, and other limitations around the site, satellite
imagery has become a very important tool in evaluating these site-
specific factors. In fact, the major air pollution control original
equipment manufacturers use satellite imagery to assist them in
estimating site congestion issues, determining location of construction
equipment and other limitations on and around the site in this way.
Site visits are also useful, but are normally performed in addition to
rather than in lieu of careful examination of satellite images. For
example, in their comments to EPA in 2010, the Utility Air Regulatory
Group used satellite photographs to demonstrate the relative difficulty
of different SCR installations.\153\
---------------------------------------------------------------------------
\153\ Cichanowicz, E., ``Current Capital Cost and Cost-
Effectiveness of Power Plant Emissions Control Technologies'',
Prepared for Utility Air Regulatory Group, January 2010.
---------------------------------------------------------------------------
While a site visit can be useful and provide additional
information, assessing satellite imagery provides adequate information
to determine access to the site, access around the boilers,
availability of space for locating construction equipment and
materials, and whether buildings or equipment must be demolished to
make room for the equipment. Notably, the budgetary price provided to
PacifiCorp from Babcock & Wilcox was not developed from a site visit.
Per the cover page of the budgetary proposal, ``[g]iven the budgetary
nature of this request, we have not made site visits to consider layout
options: instead, we have used available drawings and made necessary
assumptions to enable us to establish a basis to derive quantities of
material and associated costs.''
For SCR installations, site visits and more detailed boiler
drawings provide additional information regarding air preheater
location and whether it must be relocated to make room for the SCR, or
if ductwork limitations require demolition of other large pieces of
equipment such as ESPs. Such costs will significantly increase the cost
of retrofitting an SCR. However, relocation of the air preheater or ESP
was not identified as a concern by any of the commenters. Instead, most
commenters raised retrofit issues that are commonly encountered in SCR
retrofits, including location of SCR support steel and possible
interferences with other equipment on site; penetration of boiler
building by SCR ductwork; location of cranes for units that are side-
by-side; the need for increased fan capacity and associated electrical
modifications; and stiffening of ductwork due to increased pressure
drop from SCR. As a result, the retrofit costs in the IPM algorithms
that were developed from actual SCR projects should capture these more
common retrofit issues and to the extent that some situations seem more
difficult, can be addressed with retrofit factors.
In its cost estimates, PacifiCorp provided a long comparative table
(over 100 rows with 25 columns of data) for Dave Johnston 3 and
Naughton 1 and 2 showing different cost estimating methods. The table
showed vendor budgetary pricing for Direct Capital Costs based upon a
proposal from Babcock & Wilcox. While EPA accepts the proposal from
Babcock & Wilcox as part of our final action, we have a few general
comments. The proposal, while providing a detailed total scope of
supply, provides a total cost for the project without line items. In
addition, the items included under the Owner's scope by Black and
Veatch are limited to: Boiler modifications; air-preheater
modifications; medium voltage power source; asbestos, lead, and
polychlorinated biphenyls (PCB) remediation; commercial licenses and
permits; and spare parts. Some of these costs, such as air-preheater
modifications, will not be required, while others will have a small to
modest impact on the overall cost. Notably, the cost estimate includes
items like potable water systems, fire protection, service water, other
assorted auxiliaries, as well as roads, fences, etc. Therefore, the
proposal is close to being ``turnkey'' and includes nearly all costs
for the project. It also includes some items that would fall into the
category of General Facilities. The proposal assumes that other
modifications to the Naughton plant will result in abandonment of
existing chimneys and ESPs on Units 1 and 2. Currently, these chimneys
are in service. Babcock & Wilcox also determined that the existing fans
are likely to be sufficient for the additional draft loss from the SCR.
As was noted in the Andover Report, we think that there may be some
substantial conservatism built into the Babcock and Wilcox estimate.
For example, the proposal states that the offset of Naughton Units 1
and 2 is just enough
[[Page 5140]]
to make it impractical to make a common structure for both SCR
reactors. However, examination of the drawings in the proposal shows
that Babcock & Wilcox has sized the ductwork to compensate for the
offset so that the SCR reactors should be able to be supported with a
common structure. Also, the proposal assumes that the abandoned stacks
at both sites will be dismantled, although this does not appear to be
necessary for Naughton Unit 2 and may not be necessary for Dave
Johnston Unit 3 if shorter horizontal duct runs are used. Finally,
comparison of the cost estimate provided by PacifiCorp for Naughton
Unit 1 and 2, and Naughton 1 especially, to historical costs shows that
the costs are well in excess of what other SCRs have cost. This is
particularly perplexing because additional fan capacity is not needed,
and it is not necessary to move the air preheater.
In light of the proposal and its fairly comprehensive scope of
supply, PacifiCorp's capital cost estimate included a number of items
that EPA is not including in our cost estimate, as noted below:
1. Process Contingency: Although the CCM permits a process
contingency of 5%, in EPA's opinion this is not necessary today for SCR
on coal-fired boilers firing the coals used in Wyoming. According to
the Department of Energy's National Energy Technology Laboratory,\154\
``Process contingency is intended to compensate for uncertainty in cost
estimates caused by performance uncertainties associated with the
development status of a technology. Process contingencies are applied
to each plant section based on its current technology status.''
According to the document, for commercially available technologies,
process contingency could range from 0-10%.
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\154\ U.S. Department of Energy, National Energy Technology
Laboratory, ``Cost Estimating Methodology for NETL Assessments of
Power Plant Performance'', DOE/NETL-2011/1455, April 2011, pg 4.
---------------------------------------------------------------------------
When the CCM was issued in January 2002, SCR was commercially
available but was only emerging in application on coal-fired utility
boilers in the U.S. According to a study by Cichanowicz,\155\ there was
only about 13,000 MW of coal-fired capacity using SCR in the U.S. at
the end of 2001, with nearly all SCRs installed in the prior two years,
meaning that there was very limited long-term experience with SCR on
coal-fired units. SCR usage on coal-fired boilers has since increased
about ten-fold to about 130,000 MW of coal capacity (over 40% of all
U.S. coal capacity), and is therefore a very well proven and well
understood technology on a wide range of U.S. coals, including Powder
River Basin coal. As a result, the process contingency for SCR on coal-
fired utility boilers should be much lower today than what it was when
the CCM was issued in January 2002, which was 5%. EPA believes that for
SCR applications on utility boilers burning Powder River Basin coals
(the Wyoming utility boilers), which are very well understood SCR
applications, there should not be any need for process contingency.
---------------------------------------------------------------------------
\155\ From data in Cichanowicz, J., Muzio, L., Hein, M., ``The
First 100 GW of SCR in the U.S.,--What Have We Learned?''--2006 Mega
Symposium.
---------------------------------------------------------------------------
2. Project Contingency: Because the cost estimates developed for
PacifiCorp are already very conservative and based upon detailed
estimates of the labor and materials to build the SCR, a 15% project
contingency is excessive. According to the CCM at Section 1.1, Chapter
1, pages 1-4: ``The accuracy of the information in the Manual works at
two distinct levels. From a regulatory standpoint, the Manual
estimating procedure rests on the notion of the ``study'' (or rough
order of magnitude--ROM) estimate, nominally accurate to within 30%. This type of estimate is well suited to estimating control
system costs intended for use in regulatory development because they do
not require detailed site-specific information necessary for industry
level analyses.''
The methods and cost elements of the CCM were adapted from the
American Association of Cost Engineers, or AACE (CCM Section 1, Chapter
2, pages 2-5). AACE 16R-90 \156\ states that, ``Project Contingency is
included to cover the costs that would result if a detailed-type
costing was followed as in a definitive-type study.'' According to
National Energy Technology Laboratory (NETL), ``AACE 16R-90 states that
project contingency for a `budget-type' estimate (AACE Class 4 or 5)
should be 15% to 30% of the sum of [bare erected cost], [engineering,
procurement, and construction] fees and process contingency.'' \157\
AACE 18R-97 defines different classes of estimates, from Class 5 (least
detailed) to Class 1 (most detailed).\158\ The methodology used in the
CCM falls into a Class 4 or Class 5, while the methodology used by
PacifiCorp's contractor, Babcock and Wilcox, is clearly a far more
detailed estimate that does not leave out any aspect of the project.
Therefore, the project contingency factor is not applicable. The 15%
project contingency factor in the CCM for SCR is based upon use of the
cost-estimating method described in the CCM to develop the Total Direct
Capital Costs. It is not intended to apply to a detailed estimate that:
---------------------------------------------------------------------------
\156\ AACE Recommended Practice, AACE 16R-90; www.aacei.org/non/rps/18R-90.pdf.
\157\ U.S. Department of Energy, National Energy Technology
Laboratory, ``Cost Estimating Methodology for NETL Assessments of
Power Plant Performance'', DOE/NETL-2011/1455, April 2011, pg 5.
\158\ AACE Recommended Practice, AACE 16R-87; www.aacei.org/non/rps/18R-97.pdf.
---------------------------------------------------------------------------
Includes many cost items not explicitly included in the
estimating method described in the CCM to develop the Total Direct
Capital Costs and meant to be included in the 15% project contingency;
and
Already has substantial contingency built into it through
conservative assumptions.
In fact, the CCM discusses the importance of not double-counting
contingency in multiple places, such as retrofit factor and
contingency: ``Due to the uncertain nature of many estimates, analysts
may want to add an additional contingency (i.e., uncertainty) factor to
their estimate. However, the retrofit factor is a kind of contingency
factor and the cost analyst must be careful to not impose a double
penalty on the system for the same unforeseen conditions. Retrofit
factors should be reserved for those items directly related to the
demolition, fabrication, and installation of the control system. A
contingency factor should be reserved (and applied to) only those items
that could incur a reasonable but unanticipated increase but are not
directly related to the demolition, fabrication, and installation of
the system. For example, a hundred year flood may postpone delivery of
materials, but their arrival at the job site is not a problem unique to
a retrofit situation.'' (emphasis added). The CCM, therefore,
explicitly anticipates that some analysts may, incorrectly, apply
multiple contingencies for the same areas of uncertainty even when
using the methods described in the CCM for estimating Total Direct
Capital Costs.
Because the cost estimates developed for PacifiCorp are already
very conservative and based upon detailed estimates of the labor and
materials to build the SCR, rather than study-level estimates, they
have double-counted both the costs that are intended by the CCM to be
included in the project contingency when using the CCM method, plus
they have added additional contingency in the form of conservative
assumptions to address uncertainties in their estimate. For this
reason, a 15% project contingency is
[[Page 5141]]
excessive, and we have not revised our cost estimates to include one.
3. General Facilities: The cost estimate from Babcock & Wilcox,
submitted by PacifiCorp, includes several items that would fall into
the category of General Facilities, and in order to avoid double-
counting, EPA has not included an additional line item for General
Facilities.
Comment: The same commenter suggested that the project-specific
scopes were not reasonably accounted for in EPA's cost estimates,
particularly for Naughton Units 1 and 2 and Dave Johnston Unit 3.
Additional project-specific scope concerns (related to the addition of
SCR on-site) include limited capacity of the existing induced-draft
fans and auxiliary power system, as well as National Fire Protection
Association-related equipment reinforcement requirements. Larger, more
powerful, induced-draft fans may overload existing electrical systems,
and the electrical systems may require significant modifications.
Structural stiffening of the duct work, and equipment downstream of the
boiler and upstream of the new fans may also be required by National
Fire Protection Association regulations to operate at more negative
pressures due to the installation of the SCR. These types of costs are
not generally reflected in the base case IPM cost algorithms, but they
must be taken into consideration in the development of a project-
specific cost estimate. Wyoming had this information available in the
Wyoming SIP, but EPA failed to account for this important cost
information in its FIP.
Response: All SCR systems experience a pressure drop across the
SCR, and therefore some consideration must be made to fan capacity for
every SCR system. The algorithm used by EPA explicitly includes a
``balance of plant'' cost line item such as an allowance for additional
fans and auxiliary electrical work.\159\ As for the duct stiffening,
this is frequently necessary when new fans are installed. However, as
noted in the proposal by Babcock & Wilcox, additional fan capacity is
not expected to be necessary at Naughton Units 1 and 2 or Dave Johnston
Unit 3.
---------------------------------------------------------------------------
\159\ Sargent & Lundy, ``IPM Model--Revisions to Cost and
Performance for APC Technologies--SCR Cost Development Methodology,
FINAL'', August 2010, Table 1, pg. 5.
---------------------------------------------------------------------------
Comment: The same commenter alleged that Owner's costs were not
reasonably accounted for in EPA's cost estimates, particularly for
Naughton Units 1 and 2 and Dave Johnston Unit 3. Owner's Costs include
a variety of non-financial costs incurred by the owner to support
implementation of the air pollution control project. Owner's Costs are
project-specific, but generally include costs incurred by the owner to
manage the project, hire and retain staff to support the project, and
costs associated with third party assistance associated with project
development and financing. Owner's Costs are real costs that the owner
will incur during the project and are typically included in cost
estimates prepared for large air pollution control retrofit projects.
In fact, EPA's Coal Quality Environmental Cost (CUECost) model includes
Owner's Costs (or ``Home Office'' costs) in its air pollution control
system cost estimating workbook and interrelated set of spreadsheets.
See CUECost Workbook User's Manual Version 1.0, prepared by Raytheon
Engineers & Contractors, Inc. and Eastern Research Group, Inc., EPA
Contract No. 68-D7-0001, Appendix B, pages B-3 and B-6. Wyoming had
this information available in its SIP, but EPA failed to account for
this important cost information in its FIP.
Response: Home office fees are Owner's costs, and these are
accounted for in the CCM in the 10% allowance for Engineering and
Owner's Costs. See CCM at Section 4.2, Chapter 2, page 2-44). As
described in Table 2.5 of the CCM, engineering and home office fees
represent 10% of purchased equipment costs. In this respect, we agree
with the commenter's assertions that the CCM does discuss some of the
items that roll up into these line items. For example, the CCM does
provide for ``Engineering and Home Office Fees'' that includes the home
office and plant support costs described in the comments. We have
included the portion of Owner's Costs/Surcharge in the total cost, up
to the value specified for ``Engineering and Home Office Fees''
indicated by the CCM, which is 10%.
The cost factors used in the CCM include home office fees in the
10% that is applied to engineering fees; however, the line item for
Owner's Cost in the IPM estimate was made zero. The reason Owners Cost
was removed is that the CCM includes owner's cost with the 10% for
engineering and home office fees. A 10% engineering charge was already
applied and therefore an additional allowance for home office fees
would be greater than the cost allowed under the CCM. Even if that cost
were added at a 5% rate, it would increase capital cost by 5%. This
difference would not change the determination.
Comment: The same commenter argued that regional labor concerns
were not reasonably accounted for in EPA's cost estimates, particularly
for Naughton Units 1 and 2 and Dave Johnston Unit 3. Regional labor
concerns are not accounted for in the IPM model. Regional labor
characteristics must be taken into consideration in a site-specific
cost estimate to account for factors including labor availability,
project complexity, local climate, and working conditions. Because the
Naughton and Dave Johnston facilities are in relatively remote
locations, higher labor rates must be paid to attract the kind of
skilled workers required to construct an SCR project. In addition, the
locations are subject to extreme cold and wind that can result in
significant productivity and construction challenges and delays, adding
to the overall project cost. Wyoming had this information available in
its SIP, but EPA failed to account for this important cost information
in its FIP.
EPA's flawed analyses of incomplete ``new'' cost information
directly resulted in EPA's proposed requirements for PacifiCorp to
install SCR on Naughton Units 1 and 2 and Dave Johnston Unit 3. In
contrast, to be responsive to EPA's request for additional information,
PacifiCorp has solicited budgetary project-specific cost information
from Babcock and Wilcox, an active and uniquely positioned competitive
market participant for SCR technology, for these same units. In
conjunction with Sargent & Lundy's expertise, PacifiCorp has
incorporated the site-specific budgetary cost information from Babcock
and Wilcox into updated EPA CCM side-by-side comparisons with the
Andover Report results to further demonstrate the inaccuracies in the
new cost information developed by EPA. (The following included tables
to summarize the results of these comparisons.) It is important to note
that PacifiCorp has utilized a 20-year remaining equipment life and has
excluded AFUDC from the results in the tables for comparison purposes.
As demonstrated by the results in the tables, EPA significantly
understated costs per ton of pollutant removed. As such, EPA based its
cost-effectiveness conclusions on significantly inaccurate information.
Before taking any final action on the proposed FIP, EPA must consider
in its final BART analyses the additional cost information being
provided by PacifiCorp.
Response: EPA disagrees with this comment. The commenter claims
that remote locations require offering higher wage rates and that
conditions at the site, including inclement weather, reduce worker
productivity. Because the commenter claims that these are important
factors that impact cost, the
[[Page 5142]]
commenter should have provided data to support its assertions. The
commenter did not provide any data to demonstrate that wage rates in
the area near its facilities are higher than in more populated areas.
The commenter also did not provide any specific productivity factors or
other evidence to show how the commenter arrived at its man-hour
estimates or explain how those estimates differ from a normal
productivity. Without such information, EPA cannot review and validate
the commenter's claims that labor productivity is low or that labor
cost is high.
On the other hand, labor rates for union construction labor are
available from the Construction Labor Research Council (CLRC),\160\ and
these rates are consistently well below what appears to have been
assumed in the itemized estimate provided with Basin Electric's
comments. The difference is too large to be explained by per diem.
Because both Basin Electric and PacifiCorp used Sargent & Lundy to
prepare their cost estimates, it is reasonable to assume that both
companies have made similar assumptions. Moreover, in addition to the
high labor rates assumed, there are additional line item costs for
overtime and per diem. As a result, the estimates provided by
commenters appears to incorporate additional costs or provisions well
beyond the normal costs both in the labor rates and in the line item
for additional labor costs.
---------------------------------------------------------------------------
\160\ Construction Labor Research Council Union Wages and
Supplements, available from the National Construction Boilermaker
Employers Web site, www.nacbe.com.
---------------------------------------------------------------------------
While EPA welcomes the use of SCR vendor estimates, such as those
used by PacifiCorp, or engineering estimates, such as those provided by
Basin Electric, specific details supporting the estimates must be
provided in order for them to be useful. Without details on the scope
of supply, the estimates cannot be used as a reliable source of
information because vendor scope could potentially be in error or could
be duplicative of other costs included in the estimate elsewhere.
With regard to adjustment for regional labor concerns, neither
PacifiCorp nor Basin Electric's submittals were satisfactory.
Deficiencies in Basin Electric's submittal with regard to regional
labor concerns are addressed elsewhere in these responses to comments.
The proposal from Babcock & Wilcox, while showing a total lump sum
price, did not demonstrate how they factored in regional labor
concerns.
Comment: The IPM methodology relied upon in the Andover Report is
inconsistent with the assumptions set forth in the CCM. While EPA
states that its revised cost analyses ``followed the structure of the
EPA CCM,'' EPA acknowledges that ``we have largely used the Integrated
Planning Model cost calculations to estimate direct capital costs and
operating and maintenance costs.'' 78 FR 34749. See also Andover Update
(``In estimating the costs of controls, the following were considered:
IPM Cost Models, US EPA Air Pollution CCM.''). The IPM model is a
regulatory model that uses cost algorithms developed by Sargent & Lundy
to estimate system-wide costs of air pollution technology for adoption
of national regulations. The inputs in the IPM model do not conform to
the methodology set forth in the CCM, and neither Andover nor EPA
offers any explanation for the discrepancies. This failure epitomizes
the arbitrary and capricious nature of EPA's decision making.
A careful reading of the Andover Report evidences that Andover only
followed the CCM on a limited basis, and in doing so, read into the CCM
requirements that are non-existent, while ignoring wholesale many of
the CCM's recommendations. The following language from the report
illustrates the concern: ``The BART Guidelines recommend use of the EPA
Air Pollution CCM, and the methodology used here for estimating costs
is consistent with the recommendations in the manual, such as inclusion
of taxes, insurance and administrative costs, and the use of overnight
cost for capital cost.''
As an initial matter, the CCM does not anywhere recommend the use
of ``overnight cost'' for estimating capital costs. See Section XI.B.3.
The overnight approach assumes construction of a project ``overnight,''
which means a party would not incur any interest charges, including
AFUDC, or experience any cost escalations. While a ``constant dollar
approach'' may be read to exclude escalation, the CCM does not
recommend that users assume that the interest costs related to
constructing a capital-intensive, multi-year project will cost the same
as an off-the-shelf control technology that can be installed in a day.
Furthermore, based on the acknowledgment in its report, Andover appears
only to have followed the methodology set forth in the CCM in these
three limited respects. In all other respects, Andover relied on the
IPM cost algorithms for its SCR estimate, without regard to the CCM.
For SNCR capital costs, Andover relied on an assumed $20/kW cost rather
than using the IPM algorithms or the methodology set forth in the CCM.
The high-level cost algorithms in the IPM model and the assumed
$20/kW capital cost for SNCR resulted in a substantial underestimate of
the costs of designing and constructing both the SCR and SNCR systems.
For example, the only inputs to the IPM cost modules are unit size,
heat input, fuel type, and NOX removal efficiency. The CCM
uses these inputs, but also provides for using SCR design parameters,
such as flue gas flow rate, actual stoichiometric ratio (the amount of
reagent needed to achieve target NOX emissions), space
velocity and area velocity (a measure of flue gas resident time in the
SCR reactor), catalyst volume, SCR reactor dimensions, and reagent
consumption. The CCM methodology includes similar design parameters
specific to SNCR, which the IPM model does not include and which
Andover did not consider in its cost estimate.
Andover also used the IPM model to calculate indirect capital costs
in the SCR cost estimate. The IPM model includes in its indirect
capital cost algorithm factors for Engineering and Construction
Management, Labor, and Contractor Profit/Fees. Andover removed from the
IPM capital cost calculation both Owner's Costs and AFUDC. Moreover,
the IPM Model does not include a number of other inputs that are
included in the CCM, including preproduction costs, inventory capital,
and initial catalyst costs, and Andover did not adjust the model to
incorporate these additional costs. Andover's selection of certain IPM
model inputs and exclusion of inputs in the CCM resulted in the
substantial underestimation of the indirect capital costs necessary to
design and install an SCR system.
For SNCR, Andover arbitrarily assigned a capital cost of $20/kW,
without using the IPM algorithms or performing an analysis of direct
and indirect costs consistent with the CCM. Andover relied on the IPM
model to calculate operating and maintenance costs except for urea
reagent costs for SNCR, which uses factors that differ from those
recommended in the CCM and costs utilized by Sargent & Lundy. The
model's simplistic treatment of catalyst costs, for example, is
inconsistent with the recommendations in the CCM and underestimates
annual catalyst replacement costs for SCR and for SNCR. For SNCR,
Andover adjusted the urea utilization rate from the IPM model without
explanation, which cut in half estimated annual urea costs. Andover
also assumed urea would be used as the reagent for SCR, which
[[Page 5143]]
increased reagent costs above those calculated by Sargent & Lundy based
on the use of anhydrous ammonia.
Neither Andover nor EPA explains why the cost estimate uses only
limited portions of the CCM, or why Andover believes use of the IPM
cost methodology is somehow more representative of the costs of control
that would be incurred by Basin Electric for installation of SCR and
SNCR systems. It is inherently contradictory, and therefore arbitrary
and capricious, for EPA to base its proposed disapproval of Laramie
River BART on the alleged failures of Wyoming to follow the CCM, while
at the same time relying on a consultant's report that does not comply
with those same standards.
Response: EPA disagrees with the commenter. The methodology used by
EPA is consistent with the CCM for the following reasons: (1) EPA used
the overnight cost method, which excludes certain cost elements such as
AFUDC; (2) The comparative nature of BART costs makes use of the IPM
algorithms a reasonable approach; and (3) as demonstrated in the
Exhibit 14 of Basin Electric's comments, use of the cost equations in
the CCM would have actually resulted in lower costs than predicted by
the IPM algorithms.
Moreover, both the IPM algorithms and Sargent & Lundy's estimates
for Basin Electric are empirically based from data collected at other
projects. According to page 21 of Exhibit 14 to Basin Electric's
comments: ``. . . Cost estimates prepared for LRS are based on
equipment costs and budgetary quotes available from similar projects
and Sargent & Lundy's experience with the design and installation of
retrofit SNCR and SCR control systems. The LRS cost estimates are
conceptual in nature; thus, Sargent & Lundy did not procure equipment
quotes specifically for the LRS control systems. Rather, equipment
costs for the LRS projects are based on conceptual designs developed
for the control systems, preliminary equipment sizing developed for the
major pieces of equipment, and recent pricing for similar equipment . .
.'' As a result, the estimates provided by Basin Electric are not more
valid than those developed by EPA.
Commenter claims that AFUDC should be included in the cost
analysis. As described in our responses to other comments, the CCM
explicitly excludes AFUDC from control costs, and EPA's estimates were
correct in excluding AFUDC. This is central to the overnight cost
methodology.
Commenter is critical of EPA's method for estimating SNCR capital
cost. With regard to SNCR cost methodology, the cost of SNCR is driven
primarily by the operating cost. Capital cost has a small effect on
total cost of SNCR. Therefore, a simplifying assumption that yields a
reasonable estimate of capital cost will result in an annualized cost
accurate to within 30%. Based upon input from technology
vendors on cost for other units \161\ and based upon the fact that
EPA's contractor Andover has over 25 years of direct experience
designing, specifying and optimizing SNCR systems, $20/kW was a very
reasonable estimate. EPA's contractor also reviewed the SNCR algorithms
developed by Sargent & Lundy for EPA and is of the opinion that in most
cases $20/kW provides a better estimate than the IPM algorithm because
the IPM algorithm assumes greater economies of scale than generally
exist in SNCR applications.
---------------------------------------------------------------------------
\161\ Email from Alex Dainoff, Fuel Tech, to James Staudt,
Andover Technology Partners, Wednesday, June 27, 2012.
---------------------------------------------------------------------------
On the other hand, as will be described later in this response, the
high reported furnace temperature at Basin Electric's Laramie River
Station means that SNCR will require a more complex injection system
and will have a higher urea injection rate than what is typical for
most SNCR systems. For this reason EPA has accepted the capital cost of
SNCR estimate provided by Basin Electric. In any event, SNCR capital
cost generally has a small effect on cost compared to operating cost.
Commenter is critical of EPA's use of the IPM algorithm as not
utilizing the same input design parameters. As described in other
responses to comments, the IPM algorithm for SCR incorporates either
directly or by inference all of the inputs the commenter has raised.
But, commenter is incorrect about some of the claimed inputs.
Stoichiometric ratio, space velocity, area velocity, catalyst volume,
SCR reactor volume, and reagent consumption are not inputs to an SCR
design, but are all direct results of design calculations using the
inputs of initial NOX level, final NOX level (and
by inference percent reduction), unit size, heat rate, and fuel
characteristics--all inputs to the IPM model. Gas flow rate is also
normally calculated based upon fuel type, unit size and heat rate--
again, IPM inputs. The IPM model therefore directly develops SCR
reactor cost based upon all of the same inputs, but using algorithms
based upon a database of the cost of actually constructed units. Other
costs, such as preproduction costs and initial inventory of ammonia are
incorporated into the capital costs. In any event, these are very small
portions of total cost. Initial catalyst cost is incorporated into the
direct capital costs of the project in the IPM estimate, and in any
event, initial catalyst cost is typically a very small portion of total
capital cost.
Commenter is critical of EPA's treatment of the associated costs
for replacement catalyst. Regarding treatment of catalyst cost, EPA's
approach is reasonable, factoring in the NOX reduction,
coal, facility size, capacity factor, and catalyst cost--all of the
same factors that impact catalyst replacement cost. PacifiCorp, on the
other hand, uses excessive catalyst replacement costs. PacifiCorp's use
of $290/ft\3\ for replacement catalyst cost equates to $10,422/m\3\.
This is nearly double the current cost of new catalyst. The difference
cannot be accounted for in the labor to install catalyst, which is a
very small fraction of the catalyst cost.\162\ Moreover, replacement
catalyst is frequently regenerated catalyst which costs roughly half
the cost of new catalyst. EPA conservatively assumed new catalyst at
roughly $5,500/m\3\,\163\ when in fact most catalyst replenishments
will likely be at a much lower cost due to the extensive availability
of regenerated catalyst. As a result, EPA's catalyst costs are much
more reasonable and are in fact, conservative in light of the
availability of regenerated catalyst.
---------------------------------------------------------------------------
\162\ From data in Cichanowicz, J., Muzio, L., Hein, M., ``The
First 100 GW of SCR in the U.S.,--What Have We Learned?''--2006 Mega
Symposium, page 4.
\163\ Cichanowicz, J.E., ``Current Capital Cost and Cost-
Effectiveness of Power Plant Emissions Control Technologies''
Prepared for, Utility Air Regulatory Group, January 2010.
---------------------------------------------------------------------------
Commenters are critical of EPA's estimates of SNCR reagent
consumption. Because of the importance of reagent consumption on SNCR
system capital and operating cost, chemical utilization is an important
factor. Utilization is a measure of how efficiently the SNCR reagent
reduces NOX. With SNCR, NOX reduction does not
occur on a one-for-one basis as reagent is added because a portion of
the chemical introduced does not contribute to NOX
reduction. The utilization of reagent (normally urea) declines as
temperature (or carbon monoxide concentration) increases because more
of the urea becomes oxidized (forming NOX), which reduces
the amount of reagent available for the NOX reduction
reaction. The net difference between the amount of NOX
reduced and the amount of NOX formed equals the overall
reduction in NOX, and at a sufficiently high temperature,
NOX can actually increase as urea is injected. Hence,
furnace temperature is
[[Page 5144]]
a critical parameter in determining utilization.
Chemical utilization is equal to the percent NOX
reduction divided by the treatment rate, expressed in terms of
Normalized Stoichiometric Ratio. The IPM model assumes a default
chemical utilization rate of 15%. Commenter states that Andover
adjusted the urea utilization rate in the IPM model without
explanation. On the contrary, on page 3 of its memo, Andover provided
actual utility data and explained why 25% was a more common utilization
rate for utility boilers. Chemical utilization is a strong function of
furnace temperature, and because chemical consumption is the single
largest expense associated with SNCR, using an incorrect chemical
utilization will lead to large discrepancies in cost.
Commenter states that the furnace exit gas temperature is
2710[emsp14][deg]F. While EPA suspects that this may be in error
(high), it is the data provided by the company. If this temperature is
correct, SNCR may only be marginally effective. Sargent & Lundy
estimated a chemical utilization of 12%, which is possibly optimistic.
Information from Fuel Tech, the leading supplier of SNCR technology,
stated that at the unusually high furnace exit temperature of
2500[emsp14][deg]F, well below 2710[emsp14][deg]F assumed by Sargent &
Lundy, a 25% reduction was possible at a particular facility from a
similar NOX baseline with a Normalized Stoichiometric Ratio
of 1.75 (utilization of 14.3%). Hence, EPA will accept the 12%
utilization and 20% NOX reduction assumed by Sargent & Lundy
for Laramie River Station.\164\
---------------------------------------------------------------------------
\164\ Email from Alexander Dainoff to Jim Staudt, June 27, 2012.
---------------------------------------------------------------------------
The model in the IPM, which was developed by Sargent & Lundy,
assumes a utilization rate of 15%, which Andover's data, as well as
Fuel Tech's input, demonstrates is too low for most facilities. It is
therefore a very conservative estimate of chemical utilization. In
fact, Andover reviewed Sargent & Lundy's model when it was developed
for EPA and Sargent & Lundy did not provide any supporting data
regarding the assumed utilization rate at that time. However, in light
of the high assumed furnace temperature at Laramie River Station, EPA
is assuming a 12% chemical utilization at a 20% NOX removal
rate for those units.\165\
---------------------------------------------------------------------------
\165\ Exhibit 16 to Basin Electric comment, page 25.
---------------------------------------------------------------------------
On the other hand, in the October 28, 2013 memo by Andover for EPA,
test data for utility boilers was provided showing that 25% is a more
reasonable utilization rate for most units. Moreover, Andover's
principal has conducted numerous electric utility SNCR optimization
programs, among them are programs described in referenced papers, which
makes him qualified to make this determination.166 167 168
So, in applications where more typical furnace temperatures are
expected, a chemical utilization rate closer to 25% can be reasonably
assumed.
---------------------------------------------------------------------------
\166\ Staudt, J., Casill, R., Tsai, T., Ariagno, L.,
``Commercial Application of Urea SNCR for NOX RACT
Compliance on a 112 MWe Pulverized Coal Boiler'', 1995 EPRI/EPA
Joint Symposium on Stationary Combustion NOX Control,
Kansas City, May 16-19, 1995.
\167\ Staudt, J, Hoover, B., Trautner, P., McCool, S., Frey, J.,
``Optimization of Constellation Energy's SNCR System at Crane Units
1 and 2 Using Continuous Ammonia Measurement'', The MEGA Symposium,
Baltimore, MD, August 31-September 2, 2010.
\168\ Staudt, J.E., Kehrer, K., Poczynec, J., Cote, R., Pierce,
R., Afonso, R., and Sload, A., ``Optimizing Selective Non-Catalytic
Reduction Systems for Cost-Effective Operation on Coal-Fired
Electric Utility Boilers'', presented at ICAC Forum '98, Durham,
March 1998.
---------------------------------------------------------------------------
It is also likely that, in light of the higher furnace exit
temperature at Laramie River Station, it will be necessary to utilize a
more complex and costly injection system that requires injection of
urea into convective regions of the furnace using multiple-nozzle
lances in addition to the more typical wall injectors. For this reason,
EPA is accepting the capital cost developed by Sargent & Lundy for
Basin Electric of $16.9 million per unit.
Regarding the reagent used for SCR, as the commenter points out,
EPA's initial estimates assumed that urea would be used as the feed
reagent for SCR, which results in a higher reagent cost than for
anhydrous ammonia. Because commenters have indicated that anhydrous
ammonia will be used as a reagent rather than urea, EPA's revised
estimates assume ammonia as a reagent. This will result in lower
reagent costs. EPA is also using anhydrous ammonia costs provided by
Potash Corporation instead of the value provided by the utility.\169\
The cost used by EPA represents the actual delivered cost of anhydrous
ammonia, as quoted by a major reagent supplier.
---------------------------------------------------------------------------
\169\ Email from Potash Corporation to Andover Technology
Partners, September 27, 2013.
---------------------------------------------------------------------------
Basin Electric provided a site-specific estimate. EPA generally
supports the use of vendor quotes and site-specific estimates but only
as used within the parameters of the overnight cost methodology and the
CCM. The BART Guidelines, are clear that ``[y]ou should include
documentation for any additional information you used for the cost
calculations, including any information supplied by vendors that
affects your assumptions regarding purchased equipment costs, equipment
life, replacement of major components, and any other element of the
calculation that differs from the CCM.'' \170\ When supporting
documentation to site estimates are not provided, assumptions based
upon these cannot be considered.
---------------------------------------------------------------------------
\170\ 70 FR 39166, footnote 15.
---------------------------------------------------------------------------
Much of the documentation owners cite to support additional costs
were not provided to us. For instance, although Basin Electric provided
a table that listed their cost line items, this spreadsheet (in pdf
format), over 600 lines in length (and including line items such as
4 gravel surfacing and chain link fence), was stripped of
all cell calculations, preventing any meaningful review.
There was also inadequate explanation for how man-hour rates were
developed. For example, current union boilermaker rates for Lodge 101
(Denver) range from $57.62 per hour for a Journeyman to $60.12 per hour
for a Foreman, with apprentices at lower rates.\171\ The CLRC reports
similar union boilermaker rates in the Mountain-Northern Plains area at
$56.59/hr for July 2013.\172\ For non-union boilermakers, the cost is
expected to be less. Yet, for tasks that appear to be for boilermakers
(ductwork) rates of $90.79 per man-hour are used.\173\ This is a large
unexplained difference in cost. It may be that part of it is per diem
($55/day for over 70 miles and $70/day for over 120 miles per Lodge 101
information), but per diem does not explain the full difference. Per
diem, however, is also provided as a separate cost later in the
estimate, making the high labor rate more difficult to explain. Some
portion may be for overtime, but there is no explanation provided
(overtime is also added as a separate line item later in the estimate).
Without an explanation it is not possible to evaluate these costs,
which clearly deviate from publicly available costs for labor. In
addition to not providing the necessary required supporting
documentation, Basin Electric did not follow the overnight cost
methodology. Thus, Basin Electric has failed to meet the test that is
required to support deviations from the CCM.
---------------------------------------------------------------------------
\171\ Wage & Benefit Information, Western States Field
Constructions Bargaining Agreement, Effective January 1, 2013
through September 31, 2013.
\172\ Construction Labor Research Council Union Wages and
Supplements for the Period 07/01/2008-07/01/2013. Available from the
National Association of Construction Boilermaker Employers Web site:
www.nacbe.org.
\173\ Appendices to Exhibit 14. Page 6 of SCR estimate (pdf page
43).
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[[Page 5145]]
Comment: The IPM methodology relied upon in the Andover Report is
inconsistent with the BART Guidelines. The Guidelines require that to
conduct a cost analysis, a state must ``[i]dentify parameters'' for
emission control and then ``[d]evelop cost estimates based upon those
design parameters.'' 70 FR 39166. The cost analysis includes
development of ``estimates of capital and annual costs,'' based on the
CCM ``where possible,'' but ``tak[ing] into account any site-specific
design or other conditions identified above that affect the cost of a
particular BART technology option.'' Id. Andover failed to adhere to
the methodology set forth in the CCM ``where possible.'' More
importantly, however, Andover neither followed the three-step process
in the BART Guidelines for estimating costs of compliance nor
appropriately considered the critical site- and project-specific
variables that affect the cost of both SCR and SNCR at Laramie River.
EPA's failure to comply with its own Guidelines results in an
inaccurate cost estimate that should not form the basis of a BART
determination.
Response: EPA disagrees with the commenter. The three step process
was followed for all cost estimates for affected Wyoming units. The
three-step process requires that states (or EPA): (1) Identify the
emissions units being controlled; (2) Identify design parameters for
emission controls; and (3) Develop cost estimates based upon those
design parameters. The BART affected units were already identified by
the State and confirmed by EPA, which addresses step one.
Andover clearly identified design parameters that are included in
the spreadsheets associated with the memo under the tab ``Plant Data
Summary''. This includes plant data such as fuel, capacity, capacity
factor, heat rate, baseline and controlled NOX level,
retrofit factor and firing configuration. These parameters are directly
used in the cost analysis that developed capital and annual costs.
Andover performed the cost estimates as described in the spreadsheet.
Andover considered site and project-specific parameters as described in
other responses to comments.
Commenters may disagree with the cost methodology used by EPA, and
our response to comments regarding the cost methodology used is in
other responses; however, there is no question that EPA followed the
three-step process.
Comment: The IPM methodology relied upon in the Andover Report is
inconsistent with the three-step process in the BART Guidelines for
estimating costs of compliance. The three-step process in the BART
Guidelines requires: (1) Identification of emission units being
controlled; (2) identification of design parameters for emission
controls; and (3) development of cost estimates based on those design
parameters. 70 FR 39166. The Andover Report did not adequately define
the emission units being controlled, failed to identify appropriate
site-specific design parameters that affect cost and performance of
these controls; and developed cost estimates that are neither
technically indefensible nor representative of the costs of SCR and
SNCR systems at Laramie River.
Andover's reliance on the overly simplistic IPM model precluded an
appropriate BART analysis. First, because the IPM cost algorithms are
designed to provide high-level system cost, Andover used generalized
information regarding design and baseline operating conditions at the
Laramie River boilers to identify the emission units to be controlled.
Second, because the IPM model includes only four inputs, Andover's cost
analysis could not account for unit-specific operating parameters that
affect both design of the control system and the attendant costs of
installing the controls.
As a result, the Andover Report failed to comply with the
requirement in the BART Guidelines that cost estimates account for
site-specific variables. 70 FR 39166. The site-specific design and
operational variables have an important effect on the costs of
NOX control technologies at Laramie River, particularly the
installation of SCR. Finally, because Andover used generic inputs to an
overly simplistic model, the resulting cost estimate is not technically
defensible. As Sargent & Lundy opined ``[b]ased on our evaluation of
the Andover cost estimates, it is our opinion that cost estimates
prepared by Andover are not reflective of the costs BEPC would incur to
install air pollution control systems on LRS Units 1, 2, & 3, and that
control technology costs included in the February 7, 2013 Andover
Report should not be used to determine BART for the Laramie River
generating units.''
Response: EPA disagrees with the commenter. The three step process
requires that states (or EPA): (1) Identify the emissions units being
controlled; (2) Identify design parameters for emission controls; and
(3) Develop cost estimates based upon those design parameters.
Commenter states that ``The Andover Report did not adequately
define the emission units being controlled, failed to identify
appropriate site-specific design parameters that affect cost and
performance of these controls; and developed cost estimates that are
neither technically indefensible nor representative of the costs of SCR
and SNCR systems at LRS.'' However, the BART affected units were
clearly identified and defined in the analysis. The units are
identified and described in the memo and the associated spreadsheets.
EPA's contractor clearly identified design parameters that are
included in the spreadsheet associated with the memo under the tab
``Plant Data Summary''. This includes plant data such as fuel,
capacity, capacity factor, heat rate, baseline and controlled
NOX level, retrofit factor and firing configuration. These
parameters are directly used in the cost analysis that developed
capital and annual costs. This is the very same data as used by Sargent
& Lundy in their analysis, except that EPA did not correct for
elevation, which EPA is correcting in this response to comments and
calculations.
Andover then performed the cost estimates as described in the
spreadsheet using algorithms developed by Sargent & Lundy that utilize
the same inputs as used by Sargent & Lundy in their analysis for
commenters. Other than a site visit and an adjustment for elevation,
commenters have not identified any other inputs that they used that are
different or not the direct result of the inputs utilized by EPA. With
this response to comments EPA is correcting cost estimates for
elevation and EPA has provided detailed comments regarding how site
characteristics were addressed using available satellite imagery and
why this is a valid approach for providing estimates that are
acceptable for BART analysis.
We disagree with commenter's characterization of the cost
development methodology contained in IPM as generalized. As noted in
the documentation for IPM's cost development methodology for SCR,\174\
the cost estimate methodology is based upon two databases of actual SCR
projects. These databases include 2004 and 2006 industry cost estimates
prepared for the Midwestern Ozone Group, and a proprietary in-house
database maintained by Sargent & Lundy. The Midwestern Ozone Group
information was cross-referenced with actual 2009 projects, and
escalated accordingly. Sargent & Lundy then used the information in
these databases to develop the equations described in the cost
component taking into account the
[[Page 5146]]
pre-control NOX emission level, degree of reduction, coal
type, facility size, and numerous other unit-specific factors. While a
costly engineering evaluation that included site visits in addition to
our use of satellite imagery would potentially produce a more refined
cost estimate, we disagree that our approach has produced cost
estimates that do not adequately address site-specific issues. As noted
by EPA in our responses related to satellite imagery, EPA's use of
satellite imagery enabled us to evaluate each of the major site-
specific issues raised by commenters.
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\174\ https://www.epa.gov/airmarkets/progsregs/epa-ipm/docs/v410/Appendix52A.pdf.
---------------------------------------------------------------------------
Comment: The Andover Report fails to consider site-specific
conditions as required by the BART Guidelines. The BART Guidelines and
the CCM emphasize the importance of taking into account site-specific
conditions in developing a cost estimate, particularly with respect to
construction of SCR. 70 FR 39166 (cost estimates should ``into account
any site-specific design or other conditions . . .''). See also CCM
section 2.4, page 2-40 (with respect to SCR, ``[a]ctual selection of
the most cost-effective option should be based on a detailed
engineering study and cost quotations from system suppliers.''); id.
section 2.5.4.1, page 2-27 (``Manual deviates from its standard
approach of providing study level costs [for SCR] and, instead,
provides a detailed description of the factors'' influencing costs).
Yet as Andover acknowledges in its report, its engineers did not visit
Laramie River and had no engineering plans, process flow diagrams, or
other site-specific information regarding Laramie River when it
developed EPA's cost estimate. The only information Andover collected
regarding the site was the generating capacity of the station, annual
heat input for a baseline period, NOX emission rates for
certain years, and the type of coal burned. As a result, Andover's cost
estimation methodology fails to comply with the BART Guidelines or
follow the methodology recommended by the CCM, and the final estimate
radically underestimates the cost for SCR and SNCR at Laramie River
Station.
Moreover, Andover's use of the IPM model compounded its failure to
review site-specific considerations relevant to costing SCR or SNCR at
Laramie River Station. Indeed, the fact that the model has only four
input parameters, and does not take into account other site-specific
parameters that are required by the BART Guidelines and recommended by
the CCM, renders any resulting cost estimate both technically and
legally deficient. As noted by Sargent & Lundy, which developed the IPM
algorithms for SCR and SNCR, ``[b]ecause of the limited number of site-
specific inputs, the IPM cost algorithms provide only order-of-
magnitude control system costs, and do not provide case-by-case
project-specific cost estimates meeting the requirements of the BART
Guidelines.''
By relying on the IPM model, Andover deliberately skirted the issue
of site-specific conditions, other than the most generic inputs of unit
size, heat rate, coal type, and a retrofit factor. The Andover Report
describes the retrofit factor in such a way as to emphasize its site-
specific nature, and yet makes no attempt to carefully analyze the
site-specific variables inherent in the application of the retrofit
factor: ``The retrofit factor is a subjective factor used to account
for estimated difficulty of the retrofit that is unique to the
facility. Because site visits were not possible, the retrofit factor
was estimated from satellite images that provide some insight to the
configuration of the units and degree of congestion around the site and
in the vicinity of where the SCR would be installed. These factors
impact the ability to locate large cranes on the site--that impact how
the SCR is assembled (are large sections lifted into place or is the
SCR ``stick built''), how much duct work is needed, if the SCR must be
built onto a large, elevated steel structure or can be built near the
ground, and if other equipment must be relocated to accommodate the
space of the SCR.''
The Andover Report never provides any analysis of these site-
specific factors in determining the appropriate retrofit factor for
Laramie River. Andover merely notes that the difficulties of
retrofitting an SCR unit at Units 1 and 3 is ``average,'' and applies a
retrofit factor of 1.0 to Units 1 and 3. Andover does note that
retrofit at Unit 2 will be more difficult and added an adjustment for
retrofit difficulties at Unit 2, but with no explanation of what unique
site-specific conditions contributed to the factor. Instead, the report
notes ``a modestly higher SCR retrofit difficulty factor is assumed for
Unit 2 because access will be poorer than for Units 1 or 3.'' In sum,
Andover makes no adjustments for Units 1 or 3 and accords a 20% cost
retrofit factor to Unit 2, though it had previously noted that ``when
using the IPM Capital Cost Model, retrofit difficulties associated with
an SCR may result in capital cost increases of 30% to 50% over the base
model.'' Thus, even when it accords a retrofit factor, as it did for
Unit 2, Andover inexplicably low balls that retrofit factor and the
attendant cost increase for the SCR system. When Andover's retrofit
factors are compared across units and across facilities, it appears
that Andover arbitrarily assigned the retrofit factors without
adequately accounting for site congestion and constructability issues.
Subjective retrofit factors, especially factors randomly chosen without
knowledge of site conditions, cannot account for site-specific
circumstances as provided in the BART Guidelines.
A comparison of the broad brush approach taken by Andover with the
detailed, site specific, scoping-level study taken in the Sargent &
Lundy evaluation illustrates the inadequacies with Andover's
methodology. As an initial matter, Andover made a fundamental error by
failing to account for the effect of site elevation on the project
costs. Laramie River Station is situated at 4,750 feet above sea level,
resulting in flue gas volumes approximately 20% greater than a
similarly sized unit at sea level. These larger flue gas volumes will
require larger SCR reactors, larger duct work, and increased structural
support. None of these additional costs are accounted for in Andover's
estimate because the IPM model assumes the plant is located at sea
level. Indeed, IPM model guidance provides that ``elevation of the site
must be considered separately and factored into the MW size accordingly
due to its effects on the flue gas volume.'' Id. (citing the IPM SCR
Cost Development Document (August 2010)).
Andover's reliance on the IPM model also resulted in failure to
account for a regional labor productivity factor. Regional productivity
must be taken into consideration in a site-specific cost estimate to
account for local workforce characteristics, labor availability,
project location, project complexity, local climate and working
conditions. This is a key factor for Laramie River Station, because
experienced, knowledgeable labor is difficult to acquire and requires
premium pay, further adding to the cost of an SCR system.
The most substantial failing of the Andover Report, however, is its
reliance on an aerial photograph of the plant from Google
EarthTM to account for site-specific conditions at Laramie
River Station. There are numerous important elements that cannot be
discerned from an aerial photograph. Specifically, a Google
EarthTM photograph cannot identify: (1) The site constraints
posed by the location of the coal conveyor rooms; (2) the location of
the existing fan buildings and the space constraints between the
existing fan buildings and the existing electrostatic precipitators;
(3) the necessary information to determine duct work routing and SCR
tie-ins to the existing economizers and
[[Page 5147]]
air heaters; and (4) information regarding plant subsystems such as the
fan capacity, equipment reinforcement, auxiliary power systems,
electrical plant system capacity, and other plant subsystems that would
be affected by installation and operation of the SCR systems. Further,
the aerial photograph provides no information about where the ammonia
handling system could be located and necessary pipe routing and other
support systems for the ammonia handling system. Nor does it show the
need to penetrate the 20-story boiler wall and provide related
structural support to install duct work, to provide structural support
columns for the SCR reactors in very tight spaces, and the need for
special cranes to lift heavy equipment into place in a congested space.
While Andover indicated that some of these site-specific issues are
addressed by the retrofit factor, the fact that Andover accorded no
retrofit factor to Laramie River Station Units 1 and 3, and low balled
the retrofit factor for Unit 2, resulted in a failure to include site-
specific costs in its estimate for the Laramie River, in direct
contravention of the requirements of the BART Guidelines and
suggestions of the CCM. Site-specific conditions are illustrated in
Section 5.1.1.1 of the Sargent & Lundy Critique. Finally, Andover
failed to include costs for the balance of plant systems required for
the SCR. Sargent & Lundy Critique section 5.1.1.3. These items, which
require enlarging existing plant systems to provide for the additional
power and airflow and other systems necessary to operate the SCRs,
include the following: (1) Replacement of induced draft fans by larger
fans to support the SCR units; (2) Upgrading of the existing electrical
system to support the SCR units; (3) Structural stiffening of the duct
work downstream of the SCRs; and (4) Expand existing control system to
accommodate six new SCRs (two for each generating unit).
Wyoming used actual, site-specific data regarding the BART-eligible
sources in development of its plan. In contrast, EPA did not use site-
specific data; instead, it relied on nothing more than aerial
photographs available in the public domain.
Response: EPA disagrees with the commenter. First, as discussed
elsewhere in responses, we are no longer relying on the IPM cost
algorithms, including the application of retrofit factors, to estimate
capital costs for the Laramie River Station units. Instead, we have
evaluated the cost information provided by Basin Electric in comments
and incorporated it as appropriate. Therefore, the arguments made by
the commenter related to our use of the IPM algorithm are no longer
relevant. Nonetheless, below we discuss how our use of the IPM
algorithm in the proposed rule was based on reason and evidence and
addressed the site-specific concerns raised by the commenter.
As noted in responses to other comments, EPA adequately addressed
site-specific issues in using the IPM SCR cost model. The SCR cost
model for IPM, being developed from actual SCR retrofit data,
incorporate all of the costs that would normally be associated with an
SCR retrofit. As such, retrofit issues that are common to all SCR
retrofits are incorporated into the cost. To the extent that there are
additional costs, as described in other comments, these can be
addressed with the retrofit difficulty factor.
Basin Electric did not follow the BART guidelines in developing
their cost analyses, and importantly, did not provide adequate
documentation when they deviated from it. There are only very limited
situations under which an analyst can depart from the CCM methodology
under the BART Guidelines: ``The basis for equipment cost estimates
also should be documented, either with data supplied by an equipment
vendor (i.e., budget estimates or bids) or by a referenced source (such
as the OAQPS CCM, Fifth Edition, February 1996, EPA 453/B-96-001). In
order to maintain and improve consistency, cost estimates should be
based on the OAQPS CCM, where possible. The CCM addresses most control
technologies in sufficient detail for a BART analysis. The cost
analysis should also take into account any site-specific design or
other conditions identified above that affect the cost.'' 70 FR 39166.
This section of the BART Guidelines makes it clear that the CCM is
the intended methodology for conducting a BART cost determination. It
also states why: To maintain and improve consistency. However, the CCM
does state that site-specific conditions should be incorporated. Site-
specific conditions could include space constraints, or a design
feature that could complicate installing a control. Importantly, a
footnote at the bottom of the same page of the BART Guidelines makes it
clear that the analyses should document any deviations from the CCM:
``You should include documentation for any additional information you
used for the cost calculations, including any information supplied by
vendors that affects your assumptions regarding purchased equipment
costs, equipment life, replacement of major components, and any other
element of the calculation that differs from the CCM.''
The record does not point to any ``unusual circumstance'' that
explains why Basin Electric's SCR costs are higher than costs of SCRs
at other similar facilities, other than the use of a different cost
methodology. In fact, there is nothing in the record to support claims
that the cost of SCR was in fact based on detailed site-specific vendor
bids, or is in any manner more site-specific than the costs relied upon
by EPA in our proposed rule. As an example, the BART application
submitted by Basin Electric, and relied upon by Wyoming, shows that
only the cost of catalyst is based on a vendor quote.\175\ There is no
documentation to substantiate that the remaining costs are based on
vendor quotes or any other site-specific data. The mere fact that the
cost analysis was submitted by Basin Electric is not a basis to
conclude that it is somehow highly site-specific. Indeed, even the
updated cost information recently submitted by Basin Electric during
the comment period is conceptual in nature and not based on vendor
quotes. As stated on page 21 of Exhibit 14 to their comments: ``The LRS
cost estimates are conceptual in nature; thus, S&L did not procure
equipment quotes specifically for the LRS control systems. Rather,
equipment costs for the LRS projects are based on conceptual designs
developed for the control systems, preliminary equipment sizing
developed for the major pieces of equipment, and recent pricing for
similar equipment.''
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\175\ Wyoming Regional Haze SIP, Attachment A, ``Basin Electric
Power Cooperative Laramie River Station Refined BART Visibility
Modeling'', prepared for Basin Electric Power Cooperative by Black &
Veatch Corporation, July 24, 2008, Attachment 1, page 7 of 7.
---------------------------------------------------------------------------
Commenter correctly notes that EPA did not account for elevation.
EPA acknowledges that it did not account for elevation in the estimate
when using the IPM algorithm and EPA's revised estimate does account
for elevation. Commenter states that the regional labor productivity
was not factored into EPA's estimate. EPA's estimate did provide an
allowance for overtime which is a line item in the estimate labeled
``Labor Adjustment.'' However, commenter did not provide sufficient
information to evaluate commenter's estimate and how productivity
factors were developed or applied in their estimate to produce their
estimate. Labor costs comprise roughly half of the total cost of Basin
Electric's estimate of what SCR would cost to install at Laramie River
Station, and the significance of this cost makes the lack of
information very important.
[[Page 5148]]
Moreover, if this is an important element of commenter's critique of
EPA's method, they should have provided sufficient data and supporting
justifications for EPA to evaluate commenter's estimate. Notably, this
is an important deviation from the CCM and more detailed supporting
data should have been provided. As noted in EPA's responses to other
comments, the commenter has not provided any data to explain the high
labor charge rates or claimed low productivity, as required under the
BART Guidelines.
Commenter claims that ``a Google Earth\TM\ photograph cannot
identify: (1) The site constraints posed by the location of the coal
conveyor rooms''. On the contrary, the coal conveyors are prominent
features in the images \176\ and it is clear from the coal conveyors
where the coal conveyor rooms are located. This location for coal
conveyor rooms is not unusual. In general, coal conveyor rooms are
located either to one side of the boiler or the other, depending upon
the location of the coal pile to the boiler. Moreover, the resulting
need to route ductwork through the boiler building wall is commonly
performed in SCR retrofits. As such, this is not an unusual issue and
should not significantly impact retrofit cost versus a typical
retrofit.
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\176\ Review of Estimated Compliance Costs for Wyoming Electric
Generating (EGUs)--Revision of Previous Memo, memo from Jim Staudt,
Andover Technology Partners, to Doug Grano, EC/R, Inc., February 7,
2013, Figures 6a and 6b.
---------------------------------------------------------------------------
Commenter claims that EPA did not account for ``(2) the location of
the existing FD fan buildings and the space constraints between the
existing FD fan buildings and the existing electrostatic precipitators
. . .'' It is clear from the images that there is a building located
immediately below where the SCR reactor would be located, and this is
not an unusual situation. The location of the ESP is also very clearly
shown on the images. The space between the ESP and the fan rooms is
also visible from the photo in Figure 6a of the Andover memo.
Nevertheless, having to install SCR support structure in close
proximity to existing buildings or equipment, as may be necessary at
Laramie River, is not unusual because SCRs are commonly erected in that
location and buildings or other equipment are normally in the area
below. It is also possible that SCR support structure could be built to
largely avoid the forced draft fan buildings by extending beyond them
with a common support structure for all three, or at least more than
one, SCR reactor. The space between the ESP and the fan buildings is
only significant with regard to location of a crane for erection of
Unit 2, and this is why a higher retrofit difficulty is assumed for
Unit 2. Middle unit crane access issues are not unusual either and have
been addressed numerous ways, including assembling a temporary crane
above the boiler building, as was performed at the Brayton Point plant
for their Unit 3.
Commenter claims that EPA did not adequately account for ``(3) the
necessary information to determine duct work routing and SCR tie-ins to
the existing economizers and air heaters . . .'' EPA disagrees with the
commenter. The general routing can be estimated from the images, and
there was nothing in the images to suggest any problems with routing
ductwork. It was apparent that a penetration was necessary in the
boiler building, which is routinely necessary because boilers are
typically housed in boiler buildings and the SCRs are not, making
penetration of a boiler building wall necessary in any SCR retrofits
where the boiler is in a boiler building. This is the case with most
SCR retrofits. In fact, Figures 2 and 3 of Exhibit 16 to Basin
Electric's comments demonstrate that the ductwork tie in to the boiler
and associated modifications are similar to what is done routinely and
ductwork length is reasonable. For an SCR cost estimate, the most
critical cost issues that require closer examination than possible with
a satellite photo is if it is necessary to move major pieces of
equipment, such as an air preheater, in order to accommodate the
ductwork. Had it been determined that relocating the air preheater was
necessary, this would entail some significant additional cost over what
would be considered a ``typical'' retrofit. Basin Electric did not
indicate any such need and therefore their costs for ductwork are
expected to be within the normal cost for a retrofit.
Commenter claims that EPA did not properly account for ``(4)
information regarding plant subsystems such as the FD fan capacity,
equipment reinforcement, auxiliary power systems, electrical plant
system capacity, and other plant subsystems that would be affected by
installation and operation of the SCR systems. Sargent & Lundy Critique
section 5.1.1.2.-5.1.1.3.'' The IPM algorithm explicitly assumes that
it will be necessary to replace the forced draft (FD) fan \177\ and
make modifications to auxiliary electrical systems and associated
boiler structure and has a line item cost for this. As such this was
addressed in the cost.
---------------------------------------------------------------------------
\177\ Sargent & Lundy, ``IPM Model--Revisions to Cost and
Performance for APC Technologies--SCR Cost Development Methodology,
FINAL'', August 2010.
---------------------------------------------------------------------------
Commenter claims that ``Further, the aerial photograph provides no
information about where the ammonia handling system could be located,
and necessary pipe routing and other support systems for the ammonia
handling system. Nor does it show the need to penetrate the 20-story
boiler wall and provide related structural support to install duct
work, to provide structural support columns for the SCR reactors in
very tight spaces, and the need for special cranes to lift heavy
equipment into place in a congested space.'' EPA disagrees. It is
apparent from the image, and the open spaces on the images that have no
structures, that there are any of a number of places at the Laramie
River site that the ammonia storage system could be located. Selecting
the ideal location does require closer examination of the site than
possible with an aerial photograph. However, the impact on total
capital cost is relatively small. With regard to modifications to the
boiler building, this has already been discussed along with the
installation of structural support columns for the SCR and need for
cranes. These modifications are routinely necessary for SCR retrofits
and would be factored into the historical SCR projects that the IPM
algorithms are based upon.
Expansion of the controls is another cost identified by commenters
as not adequately addressed by EPA. EPA disagrees with commenter. Every
SCR retrofit requires expansion of controls. So, this is incorporated
into the IPM model. There may be specific issues that may be associated
with tailoring the controls to the existing site that make this portion
of the cost slightly more or slightly less expensive than normal. But,
controls are generally a small contributor to total SCR cost and these
differences would have a minor effect.
Comment: When all of the site-specific and balance of plant
conditions are included, Sargent & Lundy estimated that the capital
cost of installing SCR at Laramie River Station is $746,906,000. This
is twice as much as Andover's flawed cost estimate of $330,000,000. The
discrepancy in the cost estimates is not surprising in light of
Andover's failure to comply with the BART Guidelines and to follow the
CCM where appropriate. For example, the site congestion and balance-of-
plant upgrades alone total approximately $290 million--costs which
accurately reflect site-specific constraints to installing SCR, but
which were not accounted for in the Andover Report. While the costs
estimated in the Sargent
[[Page 5149]]
& Lundy Evaluation are significantly greater than those set forth in
the Andover Report, they are a far more accurate and representative
assessment of the costs of installing SCR and SNCR at Laramie River
Station.
Response: EPA disagrees with the commenter, having found the
following discrepancies in the commenter's estimates for cost of SCR
and SNCR at Laramie River Station:
1. Apparently Double-Counts General Facilities
The itemized cost estimate in the Appendices to Exhibit 14 includes
items that are normally incorporated into the General Facilities cost,
while Sargent & Lundy took an additional provision for General
Facilities (Exhibit 14 at page 31). General Facilities are costs that
are not directly associated with the process equipment, and include
such things as access roads, access platforms, safety equipment (such
as eye-wash stations), etc. On the other hand, ductwork, piping,
structural steel to support process equipment are direct capital cost
and do not fall into the category of General Facilities. The itemized
cost estimate by Sargent & Lundy in the Appendices to Exhibit 14,
however, includes the cost of many items that would normally fall under
the category of General Facilities. This includes the cost of roads and
a parking area ($930,226 at page 2 of SCR estimate), eye wash stations
(page 3), a pre-engineered building for the construction warehouse
($780,000 page 8), fire protection systems (page 16), gratings,
handrails, ladders (page 22). As a result, Sargent & Lundy double
counts for General Facilities by having these costs accounted for in
the itemized direct capital cost as well as in its Indirect Capital
costs.
2. Labor Rates in Sargent & Lundy's Itemized Capital Cost in the
Appendices to Exhibit 14 Appear To Already Have a Significant
Contingency Built in and Additional Costs for Overtime and Per Diem--
Already Incorporating Contingency in Apparent Double-Counting of
Contingency
According to Basin Electric's comments, their labor rates were
taken from the publication RS Means.\178\ However, examples of how the
labor rates from RS Means were used to develop what was ultimately used
in their estimate were not provided. RS Means is a subscription service
that can cost up to $1,100, depending upon the package.
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\178\ Exhibit 14, page 25.
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However, there are publicly available labor rates for the major
construction trades from the CLRC that are available for download at
the National Association of Construction Boilermaker Employers' Web
site.\179\ The Laramie River Station estimate assumes boilermaker labor
tasks with a labor rate of $90.79/hr while according to the CLRC
boilermaker rates in the Mountain and Northwest Plains as of July 2013
were $56.79/hour, which is close to the values for Lodge 101 of the
boilermakers union, ranging from $57.62 for a Journeyman to $60.12 for
a Foreman, and lower rates for apprentices.
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\179\ Construction Labor Research Council Union Wages and
Supplements, available from the National Construction Boilermaker
Employers Web site, www.nacbe.com.
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The Laramie River estimate assumes pipefitter labor tasks with a
labor rate of $81.72/hour, while according to the CLRC pipefitter rates
in the Mountain and Northwest Plains as of July 2013 were $43.57/hour.
Plumber rates are only slightly higher are $47.47/hour. In fact, there
are several areas where the Laramie River itemized estimated rates in
the Appendices far exceed Mountain-Northern Plains reported rates for
union craft labor for July 2013. The ratio of assumed rate versus
reported is as high as 187%. It is only for the installation of an
architectural door that the reported rate for carpenters is even close
to the assumed rate for Laramie River Station. Carpenters also build
concrete forms.\180\ For carpenters doing concrete forms, the paid rate
($65.02--see page 2 of estimate) is more than double the union rate.
For most of these crafts, these rates cannot be explained by per diem.
For example, if all of the boilermakers lived 120 miles from the
location and were eligible for $70/day per diem and also drove 120
miles each way every day of an eight-hour shift receiving $0.565/mile,
that would only increase the hourly rate by $25.70, which does not
explain the $34+ difference.
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\180\ Bureau of Labor Statistics, 47-2031 Carpenters,
www.bls.gov/oes/current/oes472031.htm.
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It may be that Sargent & Lundy applied an escalation to the labor
charges for future expected rates. If so, this is inconsistent with the
CCM, which does not allow for this. In light of the fact that labor
comprises the single largest expense and is nearly half of the total
direct cost of the project--per Basin Electric's estimate in the
Appendices to Exhibit 14--the high labor rates assumed by Sargent &
Lundy are critical cost items that require much more complete
explanation than was provided.
3. Additional Labor Costs
In addition to the high labor rates incorporated into Sargent &
Lundy's itemized estimate, roughly $47 million in additional labor
costs are included for five ten-hour days and six ten-hour days and per
diem.\181\ This schedule (which results in overtime) is stated to be
necessary to attract necessary labor.\182\ No further explanation is
provided for these costs. It is unclear why it is necessary to offer
these in light of the fact that power plant construction labor demand
is well off of its peak and is especially low in the Western States. As
a key power plant construction trade, boilermaker man-hours are a good
indication of general power plant construction activity. Boilermaker
man-hours demonstrate that labor demand is well off of past peaks, and
for the first two quarters of 2013, boilermaker employment in the
Western States is 18.6% below 2012 levels for the same period.
Boilermaker man-hours in 2012 nationally totaled 27 million, well off
the years of 2006 through 2009 that were all above 30 million, and
peaked in 2008 at over 40 million. 2012 levels were still below 2010's
rate of 28 million.\183\
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\181\ Appendices to Exhibit 14 of Basin Electric comments, page
4 of SCR estimate.
\182\ Exhibit 14, page 25.
\183\ https://nacbe.com/manhour-reports/. Also see: Staudt, J.E.,
``Engineering and Economic Factors Affecting the Installation of
Control Technologies--An update'', Developed for U.S. EPA Clean Air
Markets Division, December 15, 2011, figure 2-2 on page 12.
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It is also unclear why such high expenses are needed for overtime
and per diem, particularly in light of the high assumed wage rates
discussed earlier. Moreover, the need for overtime needs to be
incorporated into a discussion of schedule, which was not provided. The
time available for installing the SCRs may allow for spreading of
activities over longer periods of time than in past retrofit efforts
that may have allowed less time than the RHR, which allows for five
years. However, there is no discussion of the need for overtime in the
context of schedule.
4. Quantity and Cost of Materials and Impact on Labor Hours
Throughout the spreadsheets provided as Attachments to Exhibit 14
to Basin Electric's comments, no information was provided on how the
quantities of materials were estimated, such as tons of steel for
ductwork, etc. This makes it impossible to evaluate if Sargent & Lundy
estimated the correct quantities of materials, associated material
costs, or the associated hours
[[Page 5150]]
associated with erecting the materials. The spreadsheet was provided as
a pdf document, and therefore any underlying equations could not be
examined. As noted in our comments to other questions, it is necessary
to include documentation for any additional information used for the
cost calculations that differs from the CCM. Since the quantities of
materials also relate to the labor needed to install the materials,
this also impacts the labor costs estimated by Sargent & Lundy.
5. AFUDC
Sargent and Lundy includes AFUDC in its SCR cost. This cost of
about $22-$23 million cost per unit, for a total of $68 million, is not
permissible under the CCM as discussed in response to other comments.
6. Process Contingency
Although the CCM shows an allowable process contingency of 5% for
SCR, in EPA's opinion, this is not necessary today for SCR on coal-
fired boilers firing the coals used in Wyoming. According to the
Department of Energy's NETL: \184\ ``Process contingency is intended to
compensate for uncertainty in cost estimates caused by performance
uncertainties associated with the development status of a technology.
Process contingencies are applied to each plant section based on its
current technology status.'' According to this document, for
commercially available technologies process contingency could range
from 0-10%. When the CCM was issued in January 2002, SCR was
commercially available but was only emerging in application on coal-
fired utility boilers in the U.S. According to a study by
Cichanowicz,\185\ at the end of 2001, there was only about 13,000 MW of
coal SCR capacity in the U.S., with nearly all installed in the prior
two years, meaning that there was very limited long-term experience
with SCR on U.S. coals. SCR usage on coal-fired boilers has since
increased about ten times to about 130,000 MW of coal capacity (over
40% of all coal capacity) and is therefore a very well proven and well
understood technology on a wide range of U.S. coals. As a result, the
process contingency for SCR on coal-fired utility boilers should be
much lower today than what it was when the CCM was issued in January
2002--5%. EPA believes that for SCR applications on utility boilers
burning Powder River Basin coals, which are very well understood SCR
applications, there should not be a need for process contingency.
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\184\ U.S. Department of Energy, National Energy Technology
Laboratory, ``Cost Estimating Methodology for NETL Assessments of
Power Plant Performance'', DOE/NETL-2011/1455, April 2011, pg 4.
\185\ From data in Cichanowicz, J., Muzio, L., Hein, M., ``The
First 100 GW of SCR in the U.S.,--What Have We Learned?''--2006 Mega
Symposium.
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7. Sulfur Trioxide (SO3) Mitigation Measures Are Not Needed
Sargent & Lundy assumed that a SO3 mitigation system is
necessary for the Laramie River SCR. We disagree as this adds
unnecessary capital and operating cost. An SO3 mitigation
system is unnecessary because of the relatively low sulfur content of
the coal and the fact that the coal fly ash is high in free calcium
oxide. The available free lime will neutralize the SO3
making SO3 mitigation unnecessary. In fact, in the model
they developed for the IPM, Sargent & Lundy assumed that SO3
mitigation was unnecessary for boilers using coals with SO2
levels below 3 lb/MMBtu, making it unnecessary for Laramie River, which
fires a much lower sulfur coal from the Dry Fork Mine, with an
uncontrolled SO2 rate of roughly 0.50 to 1.0 lb/
MMBtu.186 187 188 In fact, Sargent & Lundy uses the same
rationale for arguing (correctly) that air preheater modifications are
not necessary to address potential ammonium bisulfate formation from an
SNCR system.\189\ Moreover, even if SO3 formation were a
legitimate concern, low oxidation SCR catalysts are available and any
additional cost impact would be very small. SO3 mitigation
is not a large capital cost compared to the other costs that contribute
to the SCR, but it is illustrative of the manner in which Sargent &
Lundy has taken efforts to overdesign the system while adding
unnecessary costs.
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\186\ Sargent & Lundy, ``IPM Model--Revisions to Cost and
Performance for APC Technologies--SCR Cost Development Methodology,
FINAL'', August 2010, page 5.
\187\ https://www.westernfuels.org/member-services/mining-operations
\188\ BNSF Mine Guide, at www.bnsf.com/customers/pdf/mineguide.pdf. SO2 calculated by multiplying sulfur
content (expressed as a decimal) times 2 million and dividing by the
heating value in Btu/lb.
\189\ Exhibit 14, page 17.
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8. Labor Productivity Factor Apparently Not Site-Specific
Basin Electric has commented that local labor productivity is a
major factor that impacts cost. However, it appears that the labor
productivity factor being selected at the site may have been broadly
applied by Sargent & Lundy at multiple sites in an inconsistent manner.
According to Basin Electric, ``Labor productivity accounts for things
such as labor availability, site access and working conditions,
climate, season changes, and project size and complexity'' and it is a
common practice on large construction projects to apply a productivity
factor to account for local worker productivity and construction site
conditions. A labor productivity factor of 1.15 was selected to account
for labor productivity in the southeastern Wyoming region as compared
to the benchmark of 1.00 for Texas, cited in Basin Electric's comments.
Although the comments refer to the Compass International Global
Construction Cost and Reference Yearbook, the value in that document
for the southeastern Wyoming region is not expressly stated, and it is
unclear if 1.15 is, in fact, the value in that document as we were not
able to confirm the number in the document referenced.\190\
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\190\ Exhibit 14, page 25.
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In another Sargent & Lundy BART analysis, performed for Oklahoma
Gas & Electric Sooner Units 1 & 2 and Muskogee Units 4 & 5, Sargent &
Lundy also used a Labor Productivity factor of 1.15.\191\ Since the
Oklahoma Gas & Electric units are in a climate far more similar to
Texas (only about 150 miles from Texas) than Wyoming, and the Oklahoma
plant likely draws from similar construction labor pools as Texas, it
seems that they should have a similar productivity factor as Texas. It
is also unusual that Sargent & Lundy would select the exact same
productivity factor for the Oklahoma BART analysis as Laramie River
Station's BART analysis, although these facilities are roughly six
hundred to seven hundred miles away, with very different climates and
draw on different labor pools. In this case, it appears that Sargent &
Lundy has used the same productivity factor for Laramie River Station
as for other BART analyses. In summary, there is no evidence that the
labor productivity factors suggested by the commenter are site-
specific.
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\191\ Oklahoma Gas & Electric, ``Sooner Units 1 & 2, Muskogee
Units 4 & 5 Dry FGD BART Analysis Follow-Up Report'', December 28,
2009, see pdf pages 28 and 43.
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9. Contractor's Fees and Profit Are Excessive
Commenter's estimate for contractor's fees Expense and Profit total
nearly $51 million, or 14% of the estimated total Labor, Material,
Subcontract, and Process Equipment.\192\ By contrast, Sargent & Lundy
estimated for the IPM algorithm total contractor fees and profits of
10% of the estimated Labor,
[[Page 5151]]
Material, Subcontract, and Process Equipment cost. When this higher
percentage is combined with a high direct cost, the contractor's fees
become excessive. The high contractor fees and profits assumed in the
Laramie River Station estimate also seem inconsistent with a weak power
plant construction market, as demonstrated by the boilermaker man-hour
data discussed earlier.
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\192\ Attachments to Exhibit 14 to Basin Electric Comments, page
4 of SCR estimate.
---------------------------------------------------------------------------
10. Labor, Material, Subcontract, and Process Equipment Costs in Excess
of Historical Norms, With Substantial Additional and Unnecessary Costs
Added
It is not unusual for owners to report excessive costs because
owners are most interested in a cost estimate that has a very low risk
of an overrun rather than a 30% cost estimate, which has a
higher risk of overrun (about 50%), but is likely to be a better
estimate of actual project cost. Commenter's estimate for total Labor,
Material, Subcontract, and Process Equipment is $361 million. Adding
Sargent & Lundy's estimated cost of scaffolding, freight, and
consumables that is in the Appendices to Basin Electric's Exhibit 14 to
their estimated Labor and Material, Subcontract, and Process Equipment
raises the cost to $383 million (Sargent & Lundy provides no supporting
documentation for this $22 million in additional cost). This is 27%
above the expected cost of $301 million (with elevation accounted for)
developed from the IPM SCR model, which is developed from actual
project data. This suggests that Sargent & Lundy made a fairly
conservative estimate of these costs for Basin Electric. But, in
addition to the cost of Labor, Material, Subcontract, and Process
Equipment, scaffolding, consumables and freight, in their estimate for
Basin Electric, Sargent & Lundy added very high costs for overtime, per
diem (that were not explained as required) and high costs for
contractor's fees and profits, and then added additional project and
process contingencies, unnecessary costs such as SO3
mitigation and un-allowed costs such as AFUDC that increased total
project cost to nearly $750 million--about double what they had
estimated in 2008.\193\ The combined effect of the conservative cost
estimates with additional contingencies or unnecessary cost adders,
results in what appears to be an unrealistically high cost.
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\193\ Attachments to Exhibit 14 to Basin Electric Comments, page
4 of SCR estimate and Exhibit 14 page 31.
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11. Project Contingency of 15% Is Too High in Light of the Method Used
and Very Conservative Underlying Assumptions
Because the cost estimates developed for Basin Electric are already
very conservative, and based upon detailed estimates of the labor and
materials to build the SCR, a 15% project contingency is excessive.
According to the CCM, Section 1.1 Chapter 1, page 1-4: ``The accuracy
of the information in the Manual works at two distinct levels. From a
regulatory standpoint, the Manual estimating procedure rests on the
notion of the ``study'' (or rough order of magnitude--ROM) estimate,
nominally accurate to within 30%. This type of estimate is
well suited to estimating control system costs intended for use in
regulatory development because they do not require detailed site-
specific information necessary for industry level analyses.''
The methods and cost elements of the CCM were adapted from the
American Association of Cost Engineers (AACE) (CCM Section 1, Chapter
2, p 2-5). AACE 16R-90 \194\ states that, ``Project Contingency is
included to cover the costs that would result if a detailed-type
costing was followed as in a definitive-type study.'' According to
NETL,\195\ ``AACE 16R-90 states that project contingency for a
``budget-type'' estimate (AACE Class 4 or 5) should be 15% to 30% of
the sum of BEC, EPC fees and process contingency.'' AACE 18R-97 \196\
defines different classes of estimates, from 5 (least detailed) to 1
(most detailed). The methodology used in the CCM falls into a Class 4
or Class 5, while the methodology used by Basin Electric in their
comments, with hundreds of line items and thousands of input
parameters, is clearly a far more detailed estimate that does not leave
out any aspect of the project.
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\194\ AACE Recommended Practice, AACE 16R-90; www.aacei.org/non/rps/18R-90.pdf.
\195\ U.S. Department of Energy, National Energy Technology
Laboratory, ``Cost Estimating Methodology for NETL Assessments of
Power Plant Performance'', DOE/NETL-2011/1455, April 2011, pg 5.
\196\ AACE Recommended Practice, AACE 16R-87; www.aacei.org/non/rps/18R-97.pdf.
---------------------------------------------------------------------------
The 15% project contingency factor in the CCM for SCR shown in
Table 2.5 on page 2-44 of Section 4.2 Chapter 2 is based upon use of
the cost estimating method described in the CCM to develop the Total
Direct Capital Costs. It is not intended to apply to a detailed
estimate that: (1) Includes many cost items not explicitly included in
the estimating method described in the CCM to develop the Total Direct
Capital Costs and meant to be included in the 15% project contingency,
and (2) Already has substantial contingency built into it through
conservative assumptions.
In fact, the CCM discusses the importance of not double-counting
contingency in multiple places such as retrofit factor and contingency
at page 2-30 of Chapter 2--Cost Estimation: Concepts and Methodology:
``Due to the uncertain nature of many estimates, analysts may want to
add an additional contingency (i.e., uncertainty) factor to their
estimate. However, the retrofit factor is a kind of contingency factor
and the cost analyst must be careful to not impose a double penalty on
the system for the same unforeseen conditions. Retrofit factors should
be reserved for those items directly related to the demolition,
fabrication, and installation of the control system. A contingency
factor should be reserved (and applied to) only those items that could
incur a reasonable but unanticipated increase but are not directly
related to the demolition, fabrication, and installation of the system.
For example, a hundred year flood may postpone delivery of materials,
but their arrival at the job site is not a problem unique to a retrofit
situation.'' (emphasis added). The CCM, therefore, explicitly
anticipates that some analysts may, incorrectly, apply multiple
contingencies for the same areas of uncertainty even when using the
methods described in the CCM for estimating Total Direct Capital Costs.
Because the cost estimates developed for Basin Electric are already
very conservative and based upon detailed estimates of the labor and
materials to build the SCR, rather than study-level estimates, they
have double-counted both the costs that are intended by the CCM to be
included in the project contingency when using the CCM method, plus
they have added additional contingency in the form of conservative
assumptions to address uncertainties in their estimate. For this reason
a 15% project contingency is excessive for their estimate.
12. The Cost Information in Exhibit 14 Does Not Appear To Be Consistent
With the Cost Information in the Appendices to Exhibit 14
The table on page 4 of the SCR cost estimate for Units 1-3 shows a
total cost of $481 million. This is inconsistent with the Total Direct
Capital Costs shown on page 31 of Exhibit 14, which total $465 million.
It is unclear what the cause of the $16 million difference is. In
either case, EPA believes that the cost is not adequately explained.
[[Page 5152]]
13. Laramie River Station Does Not Require an SNCR System With Four
Injection Zones
The Laramie River Station is a base loaded unit, with capacity
factors well above 80%. This means that the boiler rarely operates at
part load. Sargent & Lundy designed the SNCR system with four injection
zones to accommodate the ``entire load and temperature range within the
boiler''.\197\ Because the unit will rarely operate at part load and
the emission rate is a 30-day average, there is likely no need for four
injection levels. Four injection levels are only required on load-
following units that spend a significant amount of time at low or
middle loads or units that must comply with emission limits of much
shorter averaging times, such as 24 hour averages or less. In practice,
this system would be designed with two, or, at most, three injection
zones. The additional injection zone adds cost in the form of
additional injectors and furnace penetrations, and associated labor. On
the other hand, EPA has accepted Basin Electric's estimate of the cost
of the SNCR system. Although we believe that there would likely be
fewer injection levels, based upon the furnace exit temperature
reported by the company, we expect that at least one of the injection
levels will require a convective zone injection system using multi-
nozzle lances, which will increase the cost. Therefore, these effects
offset one another and we are accepting the cost provided by Basin
Electric.
---------------------------------------------------------------------------
\197\ Exhibit 14, page 17.
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14. Similar Labor Rate Issues for SNCR as for SCR Estimate
Examination of the labor rates for the Sargent & Lundy cost
estimate revealed that Sargent & Lundy assumed the same high labor
rates for crafts as they did for SCR without the rates explained
sufficiently. They also assumed an additional $2.7 million in
additional overtime and per diem rates that are not explained.\198\
---------------------------------------------------------------------------
\198\ Appendices to Exhibit 14 of Basin Electric comments, page
4 of SNCR estimate.
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For these reasons, the Sargent & Lundy capital cost estimates for
SCR and SNCR are deficient, for the reasons as described above.
However, because EPA expects that the SNCR injection system necessary
for Laramie River Station may require more costly multiple-nozzle
lances in at least one injection zone, this should offset the cost
impact of the deficiencies we have identified, and we are accepting the
capital cost of the SNCR system provided by Basin Electric equal to
$16.9 million per unit.
For the SCR capital cost at Laramie River, EPA is accepting some
costs and not others, as described in more detail in supporting
information with these comments.\199\
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\199\ Andover Technology Partners, ``Cost of NOX
Controls on Wyoming EGUs'', October 28, 2013; Wyoming EGU BART and
Reasonable Progress Costs--10/28/2013.
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Comment: We are very concerned to see that EPA has introduced a
retrofit factor greater than ``1'' (the default) for 13 of the 15 EGUs
evaluated. The IPM model used by EPA to estimate control costs in
Wyoming already includes retrofit costs in its costing algorithms. It
is generally accepted that retrofit projects will incur costs over and
above those for a ``greenfield'' site, and most of those retrofit costs
are already included in the database used to generate the IPM
algorithms. So, unless a particular situation is so extreme as to
warrant an additional retrofit factor, applying a retrofit factor to an
algorithm that already includes retrofit costs is double counting those
costs. Not only is the application of a retrofit factor not mentioned
in the Federal Register Notice, its only supporting documentation
appears in docket item EPA-R08-OAR-2012-0026-0086[1], ``Review of
Estimated Compliance Costs for Wyoming Electricity Generating Units
(EGUs)--revision of previous memo'': ``Selective Catalytic
NOX Reduction (SCR) capital cost is estimated using the IPM
algorithms with retrofit factors adjusted on a unit by unit basis.''
The retrofit factor is a subjective factor used to account for the
estimated difficulty of the retrofit that is unique to the facility.
Because site visits were not possible, the retrofit factor was
estimated from satellite images that provide some insight to the
configuration of the units and degree of congestion around the site and
in the vicinity of where the SCR would be installed. These factors
impact the ability to locate large cranes on the site--that impact how
the SCR is assembled (are large sections lifted into place or is the
SCR ``stick built''), how much ductwork is needed, if the SCR must be
built onto a large, elevated steel structure or can be built near the
ground, and if other equipment must be relocated to accommodate the
space of the SCR. When using the IPM capital cost model, retrofit
difficulties associated with an SCR may result in capital cost
increases of 30 to 50% over the base model.\200\
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\200\ Sargent & Lundy, ``IPM Model--Revisions to Cost and
Performance for APC Technologies SCR Cost Development Methodology
FINAL'', August 2010, Project 12301-007, Perrin Quarles Associates,
Inc. p 1.
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A proper estimation of retrofit factors involves more than an
inspection of satellite images. For example, EPA Region 8 visited the
four-unit Colstrip power plant in Montana before concluding that a
retrofit factor of ``1'' was appropriate. Once such a site visit is
conducted, retrofit factors should be developed for each element of the
cost analysis--not the ``blanket'' approach used by EPA here.
Another example is provided by Sargent & Lundy's ``Constructability
Review'' for addition of SCR at Navajo Generating Station. Navajo
Generating Station consists of three EGUs, with the middle unit
constrained by a coal conveyor passing through. Even so, Sargent &
Lundy estimated that construction effort would be only 25% greater for
Unit 2 than for the other two units. EPA needs to clarify why they
chose to add a retrofit factor greater than 1 (average retrofit factor
of 1.33 for 13 of 15 units reviewed) to the costs when retrofit costs
are already contained within data used to generate the IPM and when
neither Wyoming, Basin Electric, or PacifiCorp included a comparable
retrofit factor. By adding the retrofit factor, EPA has overestimated
the costs of SCR: in the case of Dave Johnston Units 1, 2, and 4 and
Wyodak Unit 1, this has led EPA to propose less-efficient controls than
SCR.
Chapter 2, ``Cost Estimation: Concepts and Methodology'' of the CCM
provides a lengthy discussion of retrofit factors. The CCM addresses
SCR retrofits specifically ``A correction factor for a new installation
versus a retrofit installation is included to adjust the capital
costs'' (Section 4, NOX Controls, Section 4.2,
NOX Post- Combustion, Chapter 2, SCR). The CCM retrofit
factor is $728/MMBtu/hr and, for medium-size boilers like Dave Johnston
Unit 4 or Wyodak, this represents a 23%-24% increase in the direct
capital cost.
EPA inconsistently and without explanation applied ``retrofit
factors'' that improperly increase the reported capital costs of SCR
installation. Such retrofit factors are intended to account for the
increased costs of unusually difficult retrofits, i.e., those that
present more challenges than assumed for the ``typical'' SCR retrofit,
for which costs are described by the IPM SCR cost module. The EPA
unjustifiably determined that only two of the fifteen Wyoming EGUs
(Laramie River Station Units 1 and 3) would be of average difficulty,
while applying increases of between 20 and 50 percent to the remaining
units. The EPA applied such retrofit factors even for units for which
the source owners did not claim above-average installation challenges.
The
[[Page 5153]]
EPA's exclusive evidence of potential retrofit challenges--satellite
images--does not support the EPA's application of retrofit factors.
(The commenter submitted a TSD that elaborated on some of these
points.)
The descriptions given of the EPA's view of the retrofit difficulty
at each plant based on satellite images make it clear that many guesses
were made and/or that the EPA erred on the side of high retrofit
difficulty to be conservative. Being conservative in cost estimates may
be acceptable if such conservatism is applied equally to all units and
if the EPA provides a reasoned basis for its assumptions, but the EPA
did not do so. The EPA assumed that the two units in the middle at Jim
Bridger ``will be somewhat more difficult to achieve access for
equipment'' and applied the highest retrofit factor of 1.5 to these
units, while for Laramie River Unit 2, the EPA assumed more retrofit
difficulty due to its location in the middle but only applied a
retrofit factor of 1.2. The EPA essentially made guesses that the
middle units may have more retrofit difficulty, and did not
consistently apply the same retrofit factors to the middle units of
these two plants. We found it telling that PacifiCorp's capital cost
estimates for installation of SCR systems at all four Jim Bridger units
(which are of equal size to each other) were identical for each unit,
and the same is true of Basin Electric's capital cost estimates for
installation of SCR systems at all three Laramie River units (which are
also equal in size). Given these facts, the EPA has no basis for its
application of a higher SCR retrofit factor for the units in the middle
(i.e., Jim Bridger Units 2 and 3 and Laramie River Unit 2).
To summarize, the EPA has not adequately justified the application
of any retrofit factor to the costs of SCR at any of the EGUs in
Wyoming, and the EPA should not apply retrofit factors to increase the
capital costs of SCR without adequate justification for those retrofit
factors. Further, the EPA must remember that the IPM cost module for
SCR is based on actual cost data for SCR retrofits, and that virtually
all SCR retrofits would have some space constraints due to most power
plants being built without ever planning for SCR installation. The EPA
should only apply a retrofit factor if it can justify that the cost of
SCR installation would noticeably deviate from a typical installation.
Response: As noted by commenter, the IPM cost model is based upon
actual retrofits and incorporates all of the costs normally associated
with retrofit of an SCR. This means that many of the retrofit issues
commenters have raised are incorporated into the base cost, which can
then be adjusted with a retrofit difficulty factor based upon the
perceived difficulty of the retrofit relative to typical retrofits. EPA
disagrees with the commenter in its assertion that the EPA
inconsistently and without explanation applied ``retrofit factors''
that improperly increase the reported capital costs of SCR
installation.
EPA applied retrofit factors while carefully considering site
conditions. Where there was uncertainty, EPA did lean toward making
more conservative estimates, which would explain the average retrofit
factor exceeding 1.0. Section 2.5.3.2 of the CCM discusses retrofit
cost considerations as ``Probably the most subjective part of a cost
estimate.'' The CCM states that, ``Since each retrofit installation is
unique, no general factors can be developed. A general rule of thumb as
a starting point for developing an appropriate retrofit factor is: The
larger the system, the more complex (more auxiliary equipment needed),
and the lower the cost level (e.g. study level, rather than detailed),
the greater the magnitude of the retrofit factor.'' Thus, retrofit
difficulty factor may factor in some uncertainty and be higher to
account for that.
In the cost estimates EPA developed, retrofit factors were
determined from satellite images using the following considerations:
(1) Available access to and from the site for transportation of
equipment and available space for laying down construction materials;
(2) Location of equipment relative to each other and whether there is a
substantial amount of demolition necessary in order to make room for
SCR equipment; and (3) Access for a crane. At a highly congested site,
crane access can be difficult and may entail a more costly approach.
Access for a crane is a particular concern for internal units when
units are located side-by-side.
There are no strict guidelines used for determining the actual
value of retrofit factors. They are a matter of judgment. Per the CCM
at 2.5.4.2 (page 2-28, Chapter 2 Cost Estimation: Concepts and
Methodology), ``[t]he proper application of a retrofit factor is as
much an art as it is a science, in that it requires a good deal of
insight, experience, and intuition on the part of the analyst.'' What
follows is the explanation for each of the retrofit factors used at
each of the sites. As will be shown, the retrofit factors were the
result of a thoughtful process, and were not arbitrary.
With regard to the Dave Johnson site, this is one of the more
congested sites in Wyoming. Per the Andover report on estimated costs
of NOX controls: ``Based upon the close proximity of the
boilers and associated equipment to one another, decommissioned
chimneys that will limit access and ability to move a crane, the coal
pile and coal conveyors that also limits access to the area of the
units where construction would occur, the office building that is
adjacent to Unit 1 and limits access, and the Unit 4 scrubber, retrofit
of an SCR on Units 1-4 would likely entail a significantly higher than
average retrofit cost. Unit 4 probably has the best access of all of
the units because there may be some space between the boiler and the
scrubber, but it is difficult to say for sure from the image and
therefore a conservatively high retrofit difficulty was used for unit 4
that is consistent with the other units.'' \201\ As noted, the site is
fairly congested for all units, justifying a high retrofit factor of
1.5 for all units, not just the middle units.
---------------------------------------------------------------------------
\201\ Andover Technology Partners, ``Cost of NOX
Controls on Wyoming EGUs'', October 28, 2013, p. 30; Wyoming EGU
BART and Reasonable Progress Costs--10/28/2013.
---------------------------------------------------------------------------
Jim Bridger is also limited on space, but not so much so as Dave
Johnston: ``Based upon the satellite photo, the SCR reactors would
likely be installed above the ESPs and ductwork routed to the boiler.
The boilers do not appear to be unusually constrained from the
perspective of installing SCR ductwork; however, access for
construction equipment will be much more difficult to achieve for the
two middle units. The scrubbers and associated piping will limit access
somewhat. Unit 4 access will be limited somewhat by the coal conveyor
and because it's scrubber takes up more room than the other scrubbers.
For this reason a retrofit difficulty factor of 1.5 is assumed for the
middle units and 1.25 for units 1 and 4.'' \202\
---------------------------------------------------------------------------
\202\ Andover Technology Partners, ``Cost of NOX
Controls on Wyoming EGUs'', October 28, 2013, p. 35; Wyoming EGU
BART and Reasonable Progress Costs--10/28/2013.
---------------------------------------------------------------------------
On the other hand, as is apparent from the satellite image, Laramie
River is a more open site than Dave Johnson. Satellite images ``show a
less constrained site than Dave Johnston, with good access to both
units 1 and 3. The coal conveyor is clearly visible and will be an
obstruction for the unit 2 SCR. As a result, retrofit difficulty of
installing SCR is expected to be average, except possibly for unit 2
which is located between units 1 and 3. Access of a crane will be
somewhat more challenging for Unit 2 and an SCR retrofit difficulty of
1.2 is assumed for estimating SCR capital cost. In all cases
[[Page 5154]]
the SCR reactor is likely to be installed above the ESP ductwork.''
\203\
---------------------------------------------------------------------------
\203\ Andover Technology Partners, ``Cost of NOX
Controls on Wyoming EGUs'', October 28, 2013, p. 39; Wyoming EGU
BART and Reasonable Progress Costs--10/28/2013.
---------------------------------------------------------------------------
Naughton is much more congested than Laramie River, although access
appears slightly better than for Dave Johnson. Per the Andover report:
Babcock & Wilcox provided cost estimates for the Naughton unit 1
& 2 SCRs. Babcock & Wilcox's estimate assumed that it would be
necessary to demolish stacks that will be abandoned after a planned
scrubber installation and they also determined that additional fan
capacity was not necessary. Babcock & Wilcox also assumed a complex
support structure would be needed, which adds cost. Babcock and
Wilcox also stated that units 1 and 2 are slightly offset which
makes it impractical to build a common support structure for the SCR
reactors; however, . . . Babcock & Wilcox has used a longer
horizontal duct run on the unit 1 SCR which places the unit 1 and
unit 2 SCR reactors side-by-side so that a common support structure
is likely to be possible, offering some potential savings from what
they have estimated. Alternatively, a shorter horizontal duct run on
unit 1 may make it possible to avoid demolition of the unit 1
chimney that will be abandoned. When using the IPM algorithm a
retrofit difficulty factor of 1.3 is assumed. This was based upon
the fact that it appeared to be a less congested site than Dave
Johnston, but there were potential challenges, such as the chimneys,
that could result in longer duct runs or additional demolition.
For unit 3 it is also unclear if there is enough space to
install the SCR reactor on the same side of the chimney as the
boiler, which, means that demolition of that chimney may be needed.
There appears to be access for construction equipment, such as a
crane, in the area east of the plant (the upper part of the photo)
and to the north of unit 3. In estimating the cost of the SCR for
unit 3, retrofit difficulty is above average because more lengthy
duct runs or demolition of the chimney are likely needed, and an
assumed retrofit difficulty factor of 1.3 is assumed for unit 3.
Hence, Naughton is assumed to be an above average retrofit
difficulty because of the potential for some significant interference
from some equipment and the possible need for longer than average duct
runs.
For Wyodak, access to the site appears good, but there are some
possible issues that might come up if the existing (but decommissioned)
ESP needs to be demolished, which was the reason for the above average
retrofit factor of 1.3. Per the Andover report:
In the event SCR were installed at the site, the SCR reactor
would likely be located above the existing (but decommissioned) ESP
shown between the boiler building and the chimney . . . There is
ample room on the site for lay down of material. Location of a crane
near the construction site appears to be possible; however, in every
direction from the boiler there is a potential interference that
might complicate crane location relative to the lay-down area.
Therefore, the difficulty of this retrofit is probably average to
perhaps above average. A conservative estimate of retrofit
difficulty of 1.3 is assumed, although a closer examination of the
site may show that a lower retrofit difficulty may be possible.\204\
\204\ Andover Technology Partners, ``Cost of NOX
Controls on Wyoming EGUs'', October 28, 2013, p. 52; Wyoming EGU
BART and Reasonable Progress Costs--10/28/2013.
---------------------------------------------------------------------------
As a result, the retrofit factors used were not arbitrary but the
result of a thoughtful process of examining the site for issues that
would affect the difficulty of the retrofit.
Comment: EPA's application of the maximum retrofit factor (1.5) to
Dave Johnston Units 1 and 2 is unsupported and leads to a significant
$1.5 million/year and $800/ton overestimation of average costs. Neither
PacifiCorp nor Wyoming proposed a retrofit factor for these units. It
is especially surprising that EPA has applied the maximum retrofit
factor to all four units at Dave Johnston, and that even an ``end''
unit like Unit 1 is considered to have the highest degree of retrofit
difficulty. It has been our experience that end units are typically the
easiest to retrofit, while the more difficult retrofits are associated
with ``middle'' units. Once the SCR costs are corrected to address the
issue discussed above, the incremental costs become $5,700-$5,800/ton
(versus $7,050/ton at Bridger Unit 2).
The EPA applied a retrofit factor of 1.5 to Dave Johnston Units 1-
3, citing close proximity of boilers, decommissioned chimneys and the
coal pile. It is not clear that these issues warrant a 50 percent
increase in SCR costs due to retrofit difficulty at Units 1-3.
Response: EPA's estimate of retrofit factor is based upon a
thoughtful consideration of the various factors described in the
previous response. With regard to the Dave Johnston site, this appears
to be one of the more difficult sites in Wyoming from the perspective
of retrofit.
Comment: EPA's application of the maximum retrofit factor (1.5) to
SCR on Dave Johnston Unit 4 is unsupported and leads to a significant
$3.8 million/year and $900/ton overestimation of average costs. Neither
PacifiCorp nor Wyoming proposed a retrofit factor for this unit. We
disagree with EPA's decision to apply the maximum retrofit factor to
all four units at Dave Johnston, and that even an ``end'' unit like
Unit 4 is considered to have the highest degree of retrofit difficulty.
It has been our experience that end units are typically the easiest to
retrofit, while the more difficult retrofits are associated with
``middle'' units.
The CCM retrofit factor is $728/MMBtu/hr and, for medium-size
boilers like Dave Johnston Unit 4 or Wyodak. This represents a 23%-24%
increase in the direct capital cost. For Dave Johnston Unit 4, the EPA
applied a retrofit factor of 1.5 to the costs of SCR because ``[t]here
may be more space available near unit 4 for a retrofit of SCR, but this
is unclear from the photograph.'' This is a very questionable basis to
justify increasing the costs of SCR by 50 percent.
Response: Because of the congestion of the overall site at Dave
Johnson plant, a large reduction of retrofit factor to well below 1.5
was not justified even though Unit 4 is an end unit. There appears to
be other equipment in the vicinity of Unit 4 that would obstruct access
and maintaining a retrofit factor of 1.5 seems reasonable.
Comment: The EPA assigned a 1.3 retrofit factor to the SCR cost
estimate for the single unit Wyodak plant. It appears the main reason
for applying this factor is because the SCR would likely have to be
placed on top of the decommissioned ESP, and that space constraints
were not an issue. Although the EPA summarized that ``. . . the
difficulty of this retrofit is probably average to above average since
it is common to have some relocation of equipment,'' the EPA applied a
30 percent increase to the SCR costs for Wyodak.
Response: As noted by the commenter, EPA determined that a retrofit
factor of 1.3 is conservative at Wyodak. But, because of the possible
items that are apparent (as described above) from the satellite
photograph and that could get in the way, it was not regarded as below
average difficulty, but perhaps something slightly above average. EPA
therefore does not believe that the retrofit factor should be lower
than 1.0 and it may be as high as 1.3. EPA is basing its cost analysis
on the more conservative estimate.
Comment: In Montana, EPA used the IPM algorithms for some sources
and not for others, asserting only that use of IPM ``was intended to
ensure that the direct capital costs reflect the most recent cost
levels seen in the marketplace'' and thus did not over-estimate costs.
77 FR 57888. EPA also used IPM for the Arizona FIP but failed to
address how its use was consistent with either the BART Guidelines or
the CCM. 77 FR 72512 (Dec. 5, 2012). In Colorado, EPA said the State's
cost
[[Page 5155]]
estimates for Craig Unit 1 deviated from the CCM but accepted them
anyway because EPA was pleased with a State law that required emission
reductions from certain other EGUs. 77 FR 76875. EPA sometimes
supplements the CCM with a rule that installed SCR retrofit costs must
fall between $79/kW and $316/kW, unless the state justifies a deviation
from this range. North Dakota SIP, 77 FR 20929; Montana FIP, 77 FR
57889; New Mexico FIP, 76 FR 52388, 52392. EPA has proposed to apply
this rule to the Wyoming SIP and FIP, 78 FR 34738. This cost range is
derived from ``industry studies'' and does not appear anywhere in the
CCM. Supplementing the CCM with this new requirement is inconsistent
from the terms of the CCM and BART Guidelines.
Response: We agree that we have used the IPM control cost
algorithms in various regional haze rulemakings as noted by the
commenter. And as noted by the commenter, our intent in using the IPM
cost algorithms was to ensure that our capital cost estimates for SCR
reflect those currently found in the marketplace. Elsewhere in these
responses to comments, we have documented in some detail how our use of
the IPM algorithms is consistent with the BART Guidelines and CCM. We
disagree that we have supplemented the CCM with a rule that retrofit
costs must fall between $79/kW and $316/kW--2010 dollars ($81/kW to
$324/kW when escalated to 2013 dollars), which was the range of actual
installed capital costs found in recent industry studies as cited in
our final rule for North Dakota. In the North Dakota rulemaking, we
used this information to assess whether costs supplied to EPA by states
or sources were consistent with those observed in the industry for
numerous other retrofits spanning a wide range of retrofit
difficulties. As such, this in no way represents a requirement imposed
by EPA; rather, it represents a very practical means by which EPA has
gauged the validity of costs. We acknowledge that, given exceptionally
difficult retrofit circumstances or other factors, it is possible for a
particular retrofit to fall outside of this range. In fact, we note
that our revised costs supporting this final rule are in some cases in
excess of the cited range. Our revised SCR costs for BART EGUs, when
represented on a dollar per kilowatt basis, range from $222/kW to $467/
kW, with a median cost of $322/kW (2013 dollars).\205\ From this, it is
clear that we have not established a requirement that SCR capital costs
fall within the cited range as suggested by the commenter. For our
Colorado final action, we are currently in litigation over our approval
of the State's BART determination for Craig.
---------------------------------------------------------------------------
\205\ Andover Technology Partners, ``Cost of NOX
Controls on Wyoming EGUs,'' October 28, 2013; Wyoming EGU BART and
Reasonable Progress Costs--10/28/2013; Wyoming EGU BART and
Reasonable Progress Costs for Jim Bridger--10/28/2013.
---------------------------------------------------------------------------
Comment: EPA inappropriately claimed that ``Wyoming's SCR capital
costs on a $/kW basis often exceeded real-world industry costs'' (78 FR
34748) and then refers to industry studies conducted between 2002 and
2007 that report installed unit capital costs actually incurred by
owners broadly ranging ``from $79/kW to $316/kW (2010 dollars).'' Id.
EPA also noted ``instances'' in its proposed FIP ``in which Wyoming's
source-based cost analyses did not follow the methods set forth in the
EPA CCM.'' EPA is simply incorrect in stating that Wyoming's analyses
were flawed and did not reflect real-world industry costs for the units
being analyzed. The commenter states that they are presenting
information on the ``real-world'' costs for the upcoming Jim Bridger
Units 3 and 4 SCR projects, which recently were competitively bid for
engineering, procurement, and construction contracts to be installed in
accordance with the requirements in the Wyoming SIP. These real-world
costs, in turn, can easily be compared to the costs assessed by Wyoming
and by EPA in their BART determinations.
Even when including AFUDC, the Wyoming SIP cost basis aligns
closely with the EPA's cost basis, with each agency again understating
real world costs for these projects. By extension, this real-world cost
information for Jim Bridger Units 3 and 4 validates the methodology
used by Wyoming to determine cost information for each of PacifiCorp's
BART Units. This information clearly disputes EPA's claims in its FIP
that Wyoming ``did not properly or reasonably take into consideration
the costs of compliance'' and that its SCR cost analyses exceeded real
world industry costs and were flawed. Id.
Response: We disagree that it was incorrect for EPA to state
Wyoming's cost analyses for SCR were flawed. As discussed in our
proposed rule, EPA found several deficiencies with Wyoming's cost
analyses, including: Inclusion of AFUDC, inclusion of some
inappropriate owner's costs, insufficient documentation to support
vendor estimates or bids, and use of incorrect baseline emission rates.
78 FR 34749. These deficiencies represented a departure from the
procedures outlined in the CCM and BART Guidelines and, particularly
when taken collectively, had a material impact on the cost estimates.
We have addressed why each of these items are inconsistent with the CCM
and BART Guidelines in other response to comments here.
Moreover, since the time of the State's analyses, EPA has been made
aware of additional pertinent information by commenters, much of which
has been incorporated into the revised costs presented in this final
rulemaking. Examples include: Inclusion of certain costs submitted by
the facility owner's where appropriately documented, shorter useful
life for one facility, correction for elevation, use of ammonia instead
of urea as SCR reagent, revised SNCR reagent consumption for some
facilities, and use of busbar costs for auxiliary power in place of
market prices.
Regarding whether Wyoming's costs exceeded real world industry
costs, see EPA's response to comment immediately above.
Comment: Wyoming did not overestimate the costs of SCR. The EPA
claimed to have identified a number of flaws in Wyoming's cost analyses
for SCR (78 FR 34748), but only identified one flaw--that ``Wyoming's
SCR capital costs on a $/kW basis often exceeded real-world industry
costs.'' The EPA's use of the word ``often'' indicates that Wyoming's
costs did not always exceed real-world costs, but the EPA did not
explain which costs exceeded real-world costs and which did not.
The EPA specifically alleged only that the cost estimates for Dave
Johnston Units 3 and 4, Naughton Units 1, 2, and 3, and Wyodak ``are in
excess of the range of capital costs documented by various studies for
actual installations,'' and that the EPA based this conclusion of five
industry studies conducted between 2002 and 2007. The EPA did not
explain why the State was wrong to rely on vendor submitted,
engineered, site-specific cost estimates instead of reports of
installations at other facilities as long as a decade ago. The State's
costs of compliance are based on site-specific capital costs, operating
costs, and maintenance costs provided by the companies in their
applications for a state BART permit, and over 50 percent of the costs
of compliance is driven by the capital cost to engineer and physically
install a SCR system. Such costs must be evaluated on a case-by-case
basis in accordance with Appendix Y. Variable costs, including reagent
usage (ammonia), account only for 2 to 7 percent of SCR costs.
The BART Guidelines not only allow, but encourage states to take
into account
[[Page 5156]]
site-specific conditions that impact the cost of installing emission
controls. Until the EPA explains why it was unreasonable for Wyoming to
prefer site-specific, real-world costs over speculative extrapolation
of costs incurred at other facilities many years past, the EPA cannot
lawfully displace the State's judgment simply because EPA prefers one
approach over the other.
Response: We disagree that EPA only identified one material flaw in
Wyoming's costs estimates for SCR. See EPA's response to comment
immediately above where we identify several flaws. Because Wyoming's
approach to estimating SCR costs was not consistent with the BART
Guidelines and CCM, it was appropriate for EPA to revise these costs in
our proposed rule.
We agree that the BART Guidelines encourage states to take into
account site-specific conditions that impact the cost of installing
emission controls. However, we disagree with the commenter's
characterization of the State's costs of compliance for SCR as site-
specific in nature on the mere basis that they were submitted by the
sources. There is nothing in the record to support claims that these
costs were in fact based on detailed site-specific vendor bids, or are
in any manner more site-specific than those costs relied upon by EPA in
our proposed rule. As an example, the BART application submitted by
PacifiCorp for Dave Johnston Unit 3, and relied upon by Wyoming, states
that: ``Costs and schedules for the LNBs and OFA, SNCR, and SCR were
furnished to CH2M HILL by PacifiCorp, developed using Sargent and
Lundy's internal proprietary database, and supplemented (as needed) by
vendor-obtained price quotes. The relative accuracy of these cost
estimates is stated by S&L to be in the range of plus or minus 20
percent.'' \206\
---------------------------------------------------------------------------
\206\ Wyoming Regional Haze SIP, Attachment A, ``BART Analysis
for Dave Johnston Unit 3,'' prepared for PacifiCorp by CH2MHILL,
December 2007, page 3-7.
---------------------------------------------------------------------------
From this, it is clear that PacifiCorp, and thereby also the State,
based SCR costs on ``S&Ls internal database'' and not a unique
quotation specific to Dave Johnston Unit 3 supplied by an SCR vendor.
Moreover, while the BART application refers to ``vendor-obtained
quotes,'' it does not make clear for which items these quotes were
obtained, if any, nor are any quotes for SCR included in the BART
application. Instead, the total installed capital cost of SCR (with
combustion controls) is shown in PacifiCorp's economic analysis as a
single line item with a value of $83,301,164, but without any detail or
supporting documentation.\207\ In an update to its initial BART
application, PacifiCorp subsequently increased the capital cost to
$129,700,000, but again without any detail or supporting
documentation.\208\
---------------------------------------------------------------------------
\207\ Wyoming Regional Haze SIP, Attachment A, ``BART Analysis
for Dave Johnston Unit 3,'' prepared for PacifiCorp by CH2MHILL,
December 2008, Attachment 1.
\208\ Wyoming Regional Haze SIP, Attachment A, ``Addendum to
Dave Johnston Unit 3 BART Report,'' prepared for PacifiCorp by
CH2MHILL, March 26, 2008, Attachment 1.
---------------------------------------------------------------------------
We note that the capital cost estimates for SCR presented by EPA in
our proposed rule were also based on the Sargent & Lundy databases as
these in turn underlie the IPM cost algorithms. As such, the commenter
is mistaken when characterizing Wyoming's capital costs as superior to
those from EPA. However, the costs presented by EPA went on to correct
the deficiencies that we have identified elsewhere (e.g., improper
calculation of baseline emissions). Therefore, the capital costs
provided from each agency were ultimately generated in a similar
manner, but only the overall costs generated by EPA were in keeping
with the BART Guidelines and CCM.
It is notable that, in order to address our concerns regarding lack
of site-specific costs and associated documentation, the Wyoming
sources have submitted additional cost information during the comment
period for the proposed rule. The PacifiCorp comments include capital
costs based on a vendor budgetary quote from Babcock and Wilcox, as
opposed to capital costs based on the Sargent & Lundy databases.
Similarly, Basin Electric has submitted a consultant's report that,
while conceptual in nature and without vendor-based equipment costs,
provides a more detailed analysis of SCR costs for Laramie River than
before. These submittals contain more recent and more detailed cost
information than relied upon by Wyoming in their cost analyses. The
submission of these updated costs from the sources, intended to supply
more site-specific costs to EPA, belies claims by the commenter that
the costs originally used by the State were ``vendor submitted,
engineered, site-specific cost estimates.''
Comment: We would like to point out that while the EPA makes a
point of saying in their proposed rule that they have followed their
own guidelines in the CCM, that manual has not been updated since 2002.
Representative Lummis of Wyoming has authored language to require the
EPA to update its cost manual for the first time in over a decade. The
old data in the old handbook no longer reflects the true costs of
designing, engineering and installing controls. Before rejecting state
data on the cost of compliance, the EPA must engage states and
regulating entities to acquire real-world cost data and use that data
to update its manual.
Response: We consider the use of the broader costing methodology
used by the CCM, the overnight method, as crucial to our ability to
assess the reasonableness of the costs of compliance. Evaluation of the
cost of compliance factor requires an evaluation of the cost-
effectiveness associated with the various control options considered
for the facility. A proper evaluation of cost-effectiveness allows for
a reasoned comparison not only of different control options for a given
facility, but also of the relative costs of controls for similar
facilities. If the cost-effectiveness of a control technology for a
particular facility is outside the range for other similar facilities,
the control technology may be rejected as not cost-effective. In order
for this type of comparison to be meaningful, the cost estimates for
these facilities must be performed in a consistent manner. Without an
``apples-to-apples'' comparison of costs, it is impossible to draw
rational conclusions about the reasonableness of the costs of
compliance for particular control options. Use of the CCM methodology
is intended to allow a fair comparison of pollution control costs
between similar applications for regulatory purposes.
Just as importantly, while we have followed the broad methodology
of the CCM as required by the BART Guidelines, we have also accounted
for the cost of controls currently observed in the marketplace. In
particular, our use of the cost calculations taken from the IPM,
released in 2010, is designed to reflect modern day costs. Moreover,
operation and maintenance costs for items such as labor, reagent, and
catalyst, reflect current market values. In short, we have adhered to
the broad overnight cost methodology specified in the CCM, while
updating both capital and operation and maintenance costs to reflect
current market conditions. Therefore, the commenter is mistaken in
asserting that our costs are based on outdated information.
Comment: EPA's regional haze FIP also is improper because it
assumes BART NOX controls over $5,000 per ton are ``cost
effective.'' (See e.g., 77 FR 33053.) Appendix Y, on the other hand,
states that BART NOX control costs per ton above $1,500 are
not ``cost
[[Page 5157]]
effective.'' In the preamble to the BART Guidelines, EPA suggests that
75% of the EGUs would have BART NOX removal costs between
$100 and $1,000 per ton, and almost all of the remaining EGUs could
install sufficient BART NOX control technology for less than
$1,500 per ton. EPA also recognized in the preamble that SCR was
generally not cost effective for EGUs, except for EGUs with cyclone
boilers (where the cost per ton was less than $1,500 per ton, with an
average of $900 per ton). Based upon EPA's Preamble, BART
NOX control technology that costs more than $1,500 per ton
should not be considered ``cost effective.'' Here, EPA found BART
NOX controls with a ``cost effectiveness'' number much more
than $1,500 per ton to be ``cost effective.'' Therefore, EPA should
withdraw its regional haze FIP.
Response: We disagree with this comment. For each source subject-
to-BART, the RHR, at 40 CFR 51.308(e)(1)(ii)(A), requires that states
identify the level of control representing BART after considering the
factors set out in CAA section 169A(g), as follows: ``States must
identify the best system of continuous emission control technology for
each source subject to BART taking into account the technology
available, the costs of compliance, the energy and non-air quality
environmental impacts of compliance, any pollution control equipment in
use at the source, the remaining useful life of the source, and the
degree of visibility improvement that may be expected from available
control technology.'' 70 FR 39158. Because the preamble generally
discusses costs, this does not obviate the need for states (or EPA in
the case of a FIP) to identify the best system of continuous emission
control technology on a case-by-case basis considering the five
factors. While EPA described various dollar-per-ton costs as ``cost-
effective'' in various preambles (e.g., 70 FR 39135-39136), EPA did not
establish an upper cost effectiveness threshold for BART
determinations.
Comment: Far from stating that the CCM must be the exclusive source
of cost information, the BART Guidelines state that ``[t]he basis for
equipment cost estimates also should be documented, either with data
supplied by all equipment vendor (i.e., budget estimates or bids) or by
a referenced source (such as the EPA CCM]).'' Although the BART
Guidelines then say that cost estimates should he based on the CCM, it
also says that the CCM should only he used ``where possible.'' The
Guidelines go on to say that the CCM ``addresses most control
technologies in sufficient detail for a BART analysis.''
The CCM does not say that it addresses `all' control technologies,
just ``most'', implying that the CCM does not supply all of the
necessary information. Further, the Guidelines state that the cost
analysis should ``take into account any site-specific design or other
conditions identified above that affect the cost of a particular BART
technology option.'' Again, the CCM acknowledges that there are
conditions, design scenarios, etc. that are not addressed in the CCM
but that exist in the real world that must be addressed.
Response: We acknowledge that our BART guidelines state, ``In order
to maintain and improve consistency, cost estimates should be based on
the [CCM], where possible'' and that ``[w]e believe that the [CCM]
provides a good-reference tool for cost calculations, but if there are
elements or sources that are not addressed by the Control CCM or there
are additional cost methods that could be used, we believe that these
could serve as useful supplemental information.'' The CCM contains two
types of information: (1) Study level cost estimates of capital and
operation and maintenance costs for certain specific types of pollution
control equipment, such as SCR, and (2) a broader costing methodology,
known as the overnight method. We agree that the language of the BART
Guidelines does not require strict adherence to the study level
equations and cost methods used to estimate capital and operating and
maintenance costs.
We consider the use of the broader costing methodology used by the
CCM, the overnight method, as crucial to our ability to assess the
reasonableness of the costs of compliance. Evaluation of the cost of
compliance factor requires an evaluation of the cost-effectiveness
associated with the various control options considered for the
facility. A proper evaluation of cost-effectiveness allows for a
reasoned comparison not only of different control options for a given
facility, but also of the relative costs of controls for similar
facilities. If the cost-effectiveness of a control technology for a
particular facility is outside the range for other similar facilities,
the control technology may be rejected as not cost-effective. In order
for this type of comparison to be meaningful, the cost estimates for
these facilities must be performed in a consistent manner. Without an
``apples-to-apples'' comparison of costs, it is impossible to draw
rational conclusions about the reasonableness of the costs of
compliance for particular control options. Use of the CCM methodology
is intended to allow a fair comparison of pollution control costs
between similar applications for regulatory purposes. This is why the
BART guidelines specify the use of the CCM where possible and why it is
reasonable for us to insist that the CCM methodology be observed in the
cost estimate process. The overnight method has been used for decades
for regulatory control technology cost analyses, and its use ensures
equitable BART determinations across states and across sources.
Comment: Although EPA contends that States must conform in all
respects to the Agency's CCM, its own consultant ignores the Manual
when calculating capital costs and operating and maintenance costs, and
instead uses an entirely different methodology called the IPM. 78 FR
34749. EPA tries to finesse this problem by asserting that the
consultant followed ``the structure of'' the CCM and BART Guidelines,
id., but that simply is not true. The IPM is a fundamentally different
tool and uses a fundamentally different methodology than the CCM--it
does not follow the CCM. Therefore, to rely on the consultant's cost
report to disapprove Wyoming's cost analysis and BART analysis would be
arbitrary and capricious, and not in accordance with law.
Response: We disagree. As noted elsewhere in these responses to
comments, in our revised cost estimates, we have followed the broad
methodology of the CCM, referred to as the overnight method, while
updating capital and operating and maintenance costs to reflect current
real-world costs. In doing so, we directed our consultant (Andover) to
reconcile anything in the IPM cost algorithms that would be
inconsistent with the CCM's overnight method. For example, the IPM cost
algorithms include AFUDC, which as we have established elsewhere in
these response to comments, is not part of the overnight costs.
Accordingly, our consultant eliminated this cost when utilizing costs
derived IPM cost algorithms. In effect, we have ``squared'' the IPM-
based costs with the methodology required by the CCM.
Comment: EPA's average cost effectiveness for combustion controls
and SCR for the Laramie River units is higher than Wyoming's average
cost effectiveness. Compare, e.g., 78 FR 34773, Table 36 (Wyoming's SCR
average cost effectiveness of $3,372/ton for Unit 1) with 78 FR 34775,
Table 39 (EPA's SCR average cost effectiveness of $3.718/ton for Unit
1). The higher the cost effectiveness of a given technology, the
stronger the case for rejecting it. If the State was justified in
rejecting SCR based on its lower predicted cost of SCR, it would be
even more justified in
[[Page 5158]]
rejecting SCR if it had used EPA's higher cost. The outcome would not
have changed, and so any error alleged by EPA is not material.
EPA's incremental cost effectiveness for combustion controls plus
SCR, compared with the cost effectiveness of combustion controls plus
SNCR, is lower than Wyoming's incremental cost effectiveness. However,
in considering cost effectiveness for purposes of both its SIP
disapproval and its FIP proposal, EPA cites and relies primarily on the
average cost effectiveness for SCR, not the incremental cost. 78 FR
34776 (``[T]he cost-effectiveness for new LNBs with OFA and SCR ranges
from approximately $3600/ton to $3900/ton with significant visibility
improvement at the most impacted Class I area. . . . When considering
the cost effectiveness and visibility improvement of new LNBs plus OFA
and SCR, it is within the range of what EPA has found reasonable for
BART in other SIP and FIP actions.'') EPA refers to incremental cost
only incidentally--not as an affirmative reason for disapproving
Wyoming's BART. Id. (``We also propose to find that the incremental
cost-effectiveness does not preclude the selection of new LNBs with OFA
and SCR.'').
Response: We disagree. The commenter fails to note that the
visibility improvement presented by EPA in our proposed rule is higher
than that found by the State. The tables cited by the commenter show a
visibility improvement from SCR of 0.44 deciviews resulting from the
State's analysis, while EPA's analysis showed a visibility improvement
of 0.79 deciviews. We found that, when balancing all of the BART
factors, this level of visibility improvement was significant enough to
justify the costs associated with SCR. In our revised visibility
modeling analysis for this final rule, we have presented a lower
visibility improvement for Laramie River Unit 1 of 0.57 deciviews. We
continue to find that this level of visibility improvement, and
consideration of the other BART factors, warrants installation of SCR.
The same can be said for the other two Laramie River units.
Additionally, the SCR costs and visibility improvement for the
Laramie River units provided by the State and EPA are not directly
comparable. In the BART application submitted by Basin Electric, and
relied upon by the State, and unlike in the case of SNCR, no additional
combustion controls are assumed in the SCR control scenario. Since the
time that Basin Electric submitted the BART application to the State,
additional combustion controls have been installed on the Laramie River
units. We have taken account of these additional controls in our
analyses. When assessing the emission reductions from SCR (or SNCR),
and the associated costs and visibility improvement, we incorporated
the actual emission rates currently being achieved with the additional
combustion controls. We have presented the costs of compliance and
visibility for the additional combustion controls plus SCR, much in the
same way that the State presented the same factors for the PacifiCorp
units.
Comment: The costs of SCR plus combustion controls are cost
effective at all of the Wyoming EGUs regardless of whether the costs
are based on EPA's cost analyses or the commenter's 2012 cost analyses
conducted for the original Wyoming SIP. SCR costs for each EGU in
Wyoming, show that SCR plus combustion controls is very cost effective
for all BART-subject EGUs and also Dave Johnston Units 1 and 2.
Further, even EPA's June 2013 cost estimates for SCR plus combustion
controls show that these controls are cost effective at all Wyoming
EGUs, despite what the commenter believes are deficiencies in EPA's
cost effectiveness analyses that overestimate the costs of SCR plus
combustion controls. These costs are within the range that has been
required or proposed of other similar sources to meet BART as follows:
Final NOX BART determination for San Juan Units
1-4 requires installation of SCR at all four units to meet a
NOX emission limit of 0.05 lb/MMBtu, found that the costs
ranged from $1,987/ton to $2,651/ton of NOX removed, in 2010
dollars.
EPA Region 9 has proposed SCR as BART for Four Corners
Units 1-5 to meet a NOX limit of 0.11 lb/MMBtu at a cost
effectiveness of $2,515/ton to $3,163/ton in 2008 dollars. That
converts to $2,407/ton to $3,028/ton in 2010 dollars.
In its FIP for Montana, EPA found that the cost
effectiveness of SCR controls for Colstrip Units 1 and 2 of
approximately $3,200/ton per unit (in 2010 dollars) was reasonable.
In its FIP for Arizona regional haze, EPA is requiring SCR
along with combustion controls to meet BART at the BART-subject coal-
fired units at Apache, Cholla, and Coronado power plants at cost
effectiveness values ranging from $2,275/ton to $3,472/ton.
Response: We agree that the costs for SCR plus combustion controls
presented in our proposed rule, taken without consideration of the
remaining BART factors, may generally be considered cost effective.
However, the CAA and RHR require a consideration of all five BART
factors. For example, a control that is considered cost effective may
not be warranted if the visibility improvement is minor. Also, there
may be occasions that, while the average cost effectiveness of a
control is reasonable, the incremental cost effectiveness may not be.
In short, EPA must weigh more than just the cost effectiveness when
considering BART.
Also note that, as described elsewhere in these responses to
comments, we have revised the SCR cost estimates that we presented in
our proposed rule. In today's final rule, we have again balanced the
costs along with the remaining BART factors when considering the
selection of BART controls.
Comment: EPA's proposed FIP is arbitrary, capricious, and contrary
to law for a number of reasons, including that the EPA's BART analyses
ignored relevant data. Wyoming based its BART analyses on site-
specific, engineered, vendor submitted bids for installing emission
controls (citing the SIP Attachment A materials related to Laramie
River Station), and Basin Electric has submitted to EPA comments
extensively explaining the bases for these cost estimates, including
the substantial technical difficulty of installing SNCR and SCR at
Laramie River Station due to the design of the three units. The EPA has
disregarded the site-specific cost estimates submitted for Laramie
River Station and the other BART sources in Wyoming, and the EPA has
alleged without any specificity that Wyoming did not properly or
reasonably take into consideration the costs of compliance. The EPA
relied on the IPM Model with retrofit factors adjusted on a source-by-
source basis, instead of relying on the site-specific costs.
EPA's October 23, 2012 revised cost memo states that ``[t]he
retrofit factor is a subjective factor used to account for the
estimated difficulty of the retrofit that is unique to the facility''
and noted that these retrofit factors were determined without site
visits, but based on satellite images of the facilities. At EPA's
public hearing in Casper, Wyoming, on July 26, 2013, Basin Electric's
consultant, Kenneth Snell, explained to EPA in detail how the satellite
images fail to reveal multiple conditions specific to Laramie River
Station that make installing SCR far more expensive than EPA's
consultant assumed. EPA's failure to rebut those positions is arbitrary
and, moreover, that the EPA's methodology--
[[Page 5159]]
relying on a subjective interpretation of satellite images--is itself
arbitrary and capricious because it strains credulity to claim that one
can assess retrofit costs by simply looking at hazy satellite pictures
of a power plant.
Response: EPA disagrees. First, Wyoming's BART analysis \209\ was
based upon a 2008 cost estimate by Basin Electric, which, when adjusted
for the fact that they were performed prior to addition of combustion
controls, resulted in similar capital costs for SCR and similar cost
effectiveness. Moreover, and as noted in previous responses, the costs
submitted by Wyoming should not be considered site-specific estimates,
and therefore superior to EPA's costs, on the mere basis that they were
submitted by a source. In any case, with their comments on EPA's
reproposal, Basin Electric has roughly doubled their claimed cost of
SCR, but these were not part of the Wyoming BART analysis. These new
costs submitted by Basin Electric are presumably intended to be more
site-specific in nature than those originally submitted to the State.
---------------------------------------------------------------------------
\209\ Wyoming Department of Environmental Quality Air Quality
Division BART Application Analysis AP-6047 May 28, 2009.
---------------------------------------------------------------------------
Second, the new costs offered by Basin Electric were found to be
deficient in a number of respects that are discussed more specifically
in other responses to comments. The new costs estimates included
numerous costs that were inadequately explained or without any
supporting documentation. The new cost estimates also did not include
vendor quotes. Per Basin Electric's Exhibit 14, page 21: ``The LRS
[Laramie River Station] cost estimates are conceptual in nature; thus,
S&L did not procure equipment quotes specifically for the LRS control
systems.''
EPA also disagrees with the commenter regarding the use of
satellite images for assessing retrofit difficulty. As noted in
responses to other comments, because they provide a unique ``bird's
eye'' view, satellite images are routinely used to evaluate conditions
at a site: Available space for a crane, access to and from the site,
interferences that may exist at the site boundary, interferences
between major pieces of equipment, available space for laying down
material. With regard to SCR installation, satellite images cannot
reveal whether or not the air preheater must be relocated to
accommodate SCR ductwork; however, none of the commenters indicated
that any affected Wyoming BART sources found it necessary to relocate
their air preheater. Satellite images cannot reveal the ``ideal
location'' for reagent storage equipment, although this is not a large
impact on cost. When possible and resources allow, site visits may also
provide useful data in addition to satellite images, but these are
generally performed in addition to rather than in lieu of analysis of
satellite images.
Mr. Snell's comments are largely addressed in other comments and
broadly fall into three areas: (1) Criticism of EPA's use of the IPM
algorithm for estimating SCR cost; (2) Assertions that EPA failed to
take into account site-specific factors affecting cost; (3) Assertions
that EPA failed to take into account balance of plant systems that
would need to be upgraded. Each of these items raised by Mr. Snell as
well as the specific issues within each item has been addressed
elsewhere in other responses to comments.
Comment: It has been our experience that the effectiveness of SNCR
is highly dependent upon the characteristics of each boiler. EPA states
that SNCR typically reduces NOX an additional 20 to 30%
above combustion controls without excessive NH3 slip.
NOX reduction with SNCR is known to be greater at higher
NOX emission rates than lower rates. Accordingly, EPA has
estimated that the NOX reduction from SNCR as 30% for
initial NOX greater than 0.25 lb/MMBtu, 25% for
NOX from 0.20 to 0.25 lb/MMBtu and 20% for NOX
less than 0.20 lb/MMBtu.
To support this statement, EPA cites a memo from Jim Staudt,
Andover Technology Partners (``Review of Estimated Compliance Costs for
Wyoming Electric Generating (EGUs)--Revision of Previous Memo'', memo
from Jim Staudt, Andover Technology Partners, to Doug Grano, EC/R,
Inc., February 7, 2013, p 7), but this memo provides no evidence or
documentation to support the assumptions that these control levels can
be achieved. Such assumptions, whether or not supported, can
significantly affect the outcome of a BART determination, as EPA
explained regarding Laramie River: ``Therefore, EPA predicts that the
reduction that can be achieved with SNCR at the Laramie River units is
20%, which is much lower than the 48% assumed by Wyoming. This
significantly reduces the tons reduced by SNCR which is in turn used in
the calculation of cost effectiveness. It also affects the incremental
cost effectiveness between SNCR and SCR (both in combination with
additional combustion controls).'' The use of incremental costs in this
manner is extremely sensitive to bias due to the interjection of
control strategies based upon invalid assumptions of control
efficiency.
Another commenter stated that the EPA is wrong to claim that
Wyoming overestimated the ability of SNCR to reduce NOX. The
commenter made the following points in support of this claim:
The CCM claims that ``[r]eductions of up to 65% have been
reported for some field applications of SNCR in tandem with combustion
control equipment such as low NOX burners (LNB).''
Wyoming's estimates are entirely consistent with
demonstrated SNCR effectiveness. One study clearly concluded that
``SNCR has the capability of NOX reductions in the range of
30-60%, depending on the specific retrofit application.'' See EPRI,
Cardinal 1 Selective Non-Catalytic Reduction (SNCR) Demonstration Test
Program, at 1-2 (2000). That study showed, for example, that a 600 MW
unit equipped with LNB could reduce NOX by an amount greater
than EPA's ``typical'' results.
The EPA's AP 42, Fifth Edition, Volume I, Chapter 1:
External Combustion Sources recognizes that ``[t]he effectiveness of
SNCR depends on the temperature where reagents are injected; mixing of
the reagent in the flue gas; residence time of the reagent within the
required temperature window; ratio of reagent to NOX and the
sulfur content of the fuel that may create sulfur compounds that
deposit in downstream equipment.''
The commenter concluded that EPA's own literature, as well as other
studies, recognize that SNCR effectiveness is highly contextual and
that it can achieve reductions far in excess of Wyoming's estimates.
The commenter asserted that the EPA, without explanation,
disregarded its own position on the contextual nature of SNCR
effectiveness, and in turn disregarded Wyoming's well-reasoned analysis
by relying instead on ``typical'' NOX reductions. The
commenter believes that the EPA has practiced arbitrary decision making
because the EPA did not explain in its proposal why it now prefers a
generic approach to SNCR effectiveness in reducing NOX over
its previously expressed recognition that effectiveness depends on a
host of facility-specific factors.
Response: EPA agrees with the commenter that the effectiveness of
SNCR is highly dependent upon the characteristics of each boiler, and
those characteristics include furnace temperature, furnace CO
concentration, NOX level and other factors, but furnace
temperature, CO concentration, and
[[Page 5160]]
NOX level are most important. The tendency of NOX
reduction to decrease as the NOX concentration is reduced is
a well-established phenomenon. Utility boiler upper furnace
temperatures are typically in the range of 2000-2300 [deg]F, but can
sometimes be lower or higher. As described in Section 1.2.3, SNCR
Performance Parameters in the Control CCM, and also by Sun, Hofmann and
Pachaly in 1990, and by Muzio, Montgomery, Quartucy and Texeira in
1993,210 211 the percentage reduction in NOX is
strongly impacted by the residence time, furnace temperature and the
starting, or baseline, NOX. Because most utility boiler
furnace temperatures and residence times fall into an expected range,
the possible NOX reduction is generally related to baseline
NOX and Figure 1.5 of the CCM demonstrates the effect of
baseline NOX and temperature on NOX reduction. Of
course, there are some units that may fall outside the typical range of
furnace temperatures or CO levels, and can achieve higher or lower
levels of NOX reduction. As noted in our response to other
comments, the furnace temperatures at Laramie River Station as reported
by Basin Electric in their recently submitted comments are much higher
than typical, and this will limit the possible NOX
reduction.
---------------------------------------------------------------------------
\210\ Sun, W., Hofmann, J., and Pachaly, R., ``Post-Combustion
NOX Reduction With Urea--Theory and Practice'', Seventh
Annual International Pittsburgh Coal Conference, September 10-14,
1990.
\211\ Muzio, L., Montgomery, T., Quartucy, G., Texeira, D.,
``The Effect of Residence Time On SNCR Processes'', EPRI/EPA 1992
Joint Symposium on Stationary Combustion NOX Control, Bal
Harbor, FL, May 24-27, 1993.
---------------------------------------------------------------------------
On the other hand, EPA disagrees that EPA ``disregarded its own
position on the contextual nature of SNCR effectiveness, and in turn
disregarded Wyoming's well-reasoned analysis''. On the contrary, EPA
carefully considered the contextual situation at Laramie River Station
and the State's analysis in reaching its opinion. Experience has shown
that for utility boilers NOX reductions of 48% using SNCR
alone have only been possible from much higher NOX baselines
than exist at Laramie River Station. In practice, facility owners have
generally found that, when using SNCR, the lowest cost approach is to
first reduce NOX as far as possible with combustion controls
and then use SNCR for additional reductions beyond what combustion
controls can provide. As a result, SNCR is rarely used alone to provide
48% NOX reduction on electric utility boilers because the
baseline levels in practice are typically too low to achieve such high
NOX reduction through SNCR.
The Cardinal Station citation raised by the commenter is from a
test on a 600 MW unit that had a NOX baseline of around 450-
500 ppm of NOX \212\--in the range of about 0.6 to 0.7 lb/
MMBtu, well above the emission rate of the Laramie River Station units,
which, after additional combustion controls is about 0.19 lb/MMBtu
(annual). This unit achieved 25% NOX reduction at full load
and 30% NOX reduction at 350 MW in long term tests. As a
result, this project does not support the possibility of 48%
NOX reduction with SNCR at Laramie River Station, which has
a much lower baseline NOX level than at the Cardinal
Station.
---------------------------------------------------------------------------
\212\ Stallings, J., ``Cardinal 1 Selective Non-Catalytic
Reduction (SNCR) Demonstration Test Program. EPRI Report 1000154,
July 2000, pages 4-7 and 8-1.
---------------------------------------------------------------------------
Finally, in Exhibit 14 to Basin Electric's comments,\213\ Sargent &
Lundy states that a ``33% reduction is not likely to be achievable''
and conditionally indicates that a 20% reduction should be achievable
from a baseline emission rate of 0.19 lb/MMBtu. EPA agrees that based
upon the information that is available, 20% is a more reasonable level
of reduction to expect from SNCR at Laramie River Station.
---------------------------------------------------------------------------
\213\ Exhibit 14, pages 15, 16.
---------------------------------------------------------------------------
Comment: Contrary to EPA's assertion, Wyoming's estimate of the
reduction achievable with SNCR does not depart from the BART
Guidelines. The Guidelines do not specify the effectiveness of SNCR, so
there is no contradiction. EPA observes that Wyoming assumed that after
installation of combustion controls (new LNBs and OFA), SNCR would
reduce NOX emissions from 0.23 lb/MMBtu to 0.12 lb/MMBtu, a
48% reduction. EPA, however, insists that its consultant contends that
SNCR typically reduces NOX by 20% to 30%, depending on the
level of NOX going to the SNCR unit. According to EPA's
consultant, when the input level of NOX is 0.19 lb/MMBtu,
which EPA says was the annual average at Laramie River Station Unit 1
in 2012, then after installation of new LNBs and OFA the reduction
achievable with SNCR is only 20%. 78 FR 34748. The consultant says that
would reduce the NOX emission rate only to 0.15 lb/MMBtu.
Andover Report at 7.
The only authority cited by EPA's consultant for the assumed 20%
reduction is an October 15, 2012 email from Fuel Tech. Id. at 13. No
information is provided by EPA or its consultant about the expertise of
Fuel Tech, who at Fuel Tech sent the email, why an email from Fuel Tech
should be deemed reliable, persuasive or authoritative, or why it
should take precedence over Wyoming's analysis.
EPA's statements in the Montana FIP demonstrate that EPA's critique
of Wyoming's estimate is misplaced. In that case, EPA determined that
with an inlet concentration of 0.20 lb/MMBtu, SNCR can reduce
NOX emissions by 25%, as compared to the 20% EPA endorses
for a nearly identical inlet concentration at Laramie River Station. 77
FR 23988, 24023, 24032, 24039; 77 FR 57864, 57885-57886. EPA relied on
information from Fuel Tech to support the feasibility of a 25%
NOX reduction at this inlet concentration. 77 FR 57885. EPA
explained that: ``[H]igher NOX reductions can be achieved at
mid to low load heat inputs, possibly up to 40%. Given that the
Colstrip Unit 1 and 2 frequently operate at below full load, it is
likely that on an annual basis SNCR can achieve better than the 25%
emission reduction assumed by EPA.
EPA further explained that its review of Clean Air Markets Division
(CAMD) emissions data showed that ``there are many EGUs equipped with
SNCR (with combustion controls) that are achieving an emissions rate of
0.15 lb/MMBtu or lower on a monthly basis.'' Id. at 57886 (emphasis
added). For example, Boswell Unit 4 had a NOX rate of 0.35
lb/MMBtu with LNB and close-coupled over fire air (CCOFA). Id. With
SNCR and SOFA, the unit achieved a monthly NOX rate between
0.11 and 0.14 lb/MMBtu over a full 12 month period--a reduction of 60%
to 69%. Id. In response to comments that EPA had overstated the
benefits of SNCR, EPA stated that it would not adopt a higher post-SNCR
emission rate ``without a showing that there are circumstances unique
to Colstrip Unit 1 and 2 that would prevent SNCR from achieving the
same reductions as at Boswell Unit 4.'' Id.
Response: As noted in other comments, EPA carefully considered the
contextual situation at Laramie River Station in reaching its opinion.
The Wyoming analysis \214\ indicated that NOX was reduced by
SNCR from 0.23 lb/MMBtu to 0.12 lb/MMBtu. This seemed to be a higher
level of NOX reduction than expected and inconsistent with
other experience. The BART analysis suggests no additional
NOX reduction from OFA versus LNB. Experience has shown that
for utility boilers NOX reductions of 48% using SNCR alone
have only been possible
[[Page 5161]]
from much higher NOX baselines than exist at Laramie River
Station, and a NOX reduction from 0.19 lb/MMBtu (the
NOX emissions rate after installation of combustion
controls) to 0.12 lb/MMBtu--roughly 37% reduction--is not likely to be
feasible either. In practice, facility owners have generally found
that, when using SNCR, the lowest cost approach is to first reduce
NOX as far as possible with combustion controls and then use
SNCR for additional reductions beyond what combustion controls can
provide. Those coal-fired utility units that the commenter states are
achieving below 0.15 lb/MMBtu emission rates and are equipped with SNCR
are also using combustion controls--most often LNBs and SOFA--that
lower the NOX sufficiently that less than 20% NOX
reduction is necessary to achieve under 0.15 lb/MMBtu.
---------------------------------------------------------------------------
\214\ Department of Environmental Quality, Air Quality Division,
BART Application Analysis, AP-6047, Laramie River Station, May 28,
2009.
---------------------------------------------------------------------------
As a result, SNCR is rarely used alone to provide 48%
NOX reduction on electric utility boilers because the
baseline levels in practice are typically too low to achieve such high
NOX reduction through SNCR. In fact, Exhibit 14 to Basin
Electric's comments, Sargent & Lundy states that ``33% reduction is not
likely to be achievable'' and conditionally indicates that 20%
reduction should be achievable from a baseline emission rate of 0.19
lb/MMBtu. This is more consistent with what EPA has determined.
EPA also cited input from SNCR technology supplier, Fuel Tech,
which supports EPA's opinion that an expected NOX reduction
would be in the range of 20%. Fuel Tech is the largest supplier of SNCR
technology to the electric utility industry and is therefore a very
knowledgeable source of information on SNCR.
Comment: Wyoming did not underestimate the usage and cost of urea,
and its estimate regarding urea does not conflict with the BART
Guidelines. EPA contends that producer prices for urea have increased
over the past three years and that Wyoming's analysis is defective
because it does not take those price increases into account. EPA,
however, cannot use information not available at the time of Wyoming's
BART determination to second-guess that determination. EPA's own
Guidelines counsel that in making a BART determination, a state should
consider technologies ``available before the close of the State's
public comment period,'' but explicitly provide that ``in order to
provide certainty in the process,'' a state ``need not consider
technologies that become available after this date.'' 40 CFR Part 51,
App. Y., section IV(D)(2)(3) (emphasis added). This makes sense. Absent
some time cutoff, a state's SIP would be in a constant state of flux,
subject to constant challenge based on ever changing information and
technology not available to the State at the time it made its BART
determination. This is particularly true given the amount of time it
takes EPA to review a state's SIP. It is also consistent with 40 CFR
51.308(f), which requires states to reevaluate and revise their
regional haze SIPs every ten years. That regulation clearly
contemplates that states have a duty to take into account new
information only in connection with the required periodic SIP
revisions--not on an ongoing basis.
EPA is again overstepping its role in this process. Wyoming
completed its BART analysis in 2009, more than three years ago, and it
would have been impossible to incorporate the alleged urea price
increases in that analysis. Simply put, Wyoming's BART determination is
hardly arbitrary and capricious simply because it failed to take into
account alleged urea price increases some three years after Wyoming
completed its BART analysis. Wyoming did precisely what the Guidelines
instruct: made a BART determination based on information available
before the close of its public comment period. 40 CFR Part 51, App. Y.,
section IV(D)(2)(3). To disapprove Wyoming's cost analysis based on
information that was not available to would be to employ a ``gotcha''
approach that runs contrary to EPA's own regulations and counter to
EPA's commitment to do its job fairly and objectively. If the urea
issue is truly material, EPA should, at a minimum, allow Wyoming to
consider whether this new information would affect its BART
determination before disapproving that determination.
Another commenter made a number of the same points, stating that
changes in urea prices are not a valid basis for disapproving the
state's cost analyses, and even if they were, EPA's facts are mistaken.
According to the commenter, the EPA asserted that the BART sources
underestimated the cost of SNCR and EPA supported this conclusion by
stating that Wyoming underestimated ``SNCR reagent (urea) usage and
cost.'' The commenter indicated that the EPA did not explain how
Wyoming underestimated urea usage, but the EPA asserted that ``prices
for urea have increased in the last three years'' since Wyoming
submitted its plan to EPA.
This commenter finds it remarkable that EPA would claim that a
change in urea prices in the time since Wyoming submitted its SIP
somehow invalidates the SIP, indicating that the time that has elapsed
since Wyoming submitted its plan to EPA is due in large part to EPA's
failure to take timely action on Wyoming's plan. According to the
commenter, the EPA did not claim that Wyoming's analyses were invalid
when Wyoming submitted its plan in January 2011, and the EPA did not
explain how the change in urea market prices led Wyoming to
unreasonable conclusions. The commenter stated that the EPA appears to
believe that Wyoming and other states must constantly update their BART
analyses to account for changing urea market prices up until the date
that EPA takes final action on the plan. The commenter asserted that
under this theory, the EPA can hold SIPs hostage, waiting for commodity
prices to change, and then disapprove SIPs on that basis alone. The
commenter indicated that the EPA cited no legal basis for this theory.
The commenter noted that the BART Guidelines expressly acknowledge
that ``[i]n order to provide certainty in the process,'' states ``need
not consider technologies that become available after [the close of the
comment period on the state plan] (citing 40 CFR part 51, App. Y,
section IV(D)(2)(3)). The commenter believes that in order ``to provide
certainty in the process,'' the EPA cannot claim that state plans are
perpetually subject to invalidation as a result of changing commodity
prices. The commenter stated that the State's price for urea does not
conflict with the BART Guidelines, and EPA offers no evidence that its
price is more reliable than the State's price. Commenter provided the
following additional statements: Even if urea prices have increased,
assumptions regarding such prices do not constitute a failure to follow
the BART Guidelines because the Guidelines do not specify what the
price is or how it should be determined. EPA relies on its consultant's
report to claim that prices have increased, but that report also says
that there has been significant variability in cost. Andover Report at
7-8. There is no analysis by the consultant as to whether, given the
cited price variability, the current price is likely to go up or down
in the future or what the actual cost of urea is likely to be going
forward. The consultant relies on a single source at a single point in
time to pick a urea price to apply for the life of an SNCR
installation, with no consideration of the price variability. The
reliability of the resulting price is no greater than a roll of the
dice at Las Vegas, and EPA offers no explanation why its consultant's
price is superior to the State's price. It is merely different,
[[Page 5162]]
and this is yet another technical issue upon which EPA is required to
defer to the State's assessment.
EPA's consultant modified its initial report issued in October 2012
in the revised report issued in February 2013, purportedly to account
for an alleged change in urea prices. However, the February 2013 report
cites the very same source for current urea prices as the October 2012
report. Compare Andover Report (Oct. 23, 2012) at 7. n.23, EPA docket
cite EPA-R08-OAR-2012-0026-0081, with Andover Report (Feb. 7, 2013) at
7 n.22, EPA docket cite EPA-R08-OAR-2012-0026-0086. Both reports cite
the same 10/12/2012 email from Doug Kirk of Fuel Tech. The additional
10/15/2012 email from Jennifer Zagorsky of Potash Corp that is cited in
the October report is deleted from the February report. There is no
explanation for the change.
Moreover, urea prices are relevant to operating costs for SNCR but
are not relevant to SCR. If the State's urea prices were too low, that
would mean the State had underestimated the cost of SNCR, which is what
EPA claims in its proposal. 78 FR 34748. Such an underestimate would
have no material impact on the State's BART determination and thus
provides no basis for EPA's disapproval. Once again, this is a fact
that in retrospect supports the State's BART decision, rather than
demonstrating it to be arbitrary. If Wyoming's estimate of the cost of
SNCR should have been higher, as EPA maintains, the higher cost would
tend to add further support for rejecting SNCR--the more expensive a
control technology, the stronger the reason to reject it as BART. So if
EPA is correct in claiming the State's assumed urea price was too low,
it is incorrect in claiming this made a difference in the State's BART
determination. A mistake in a cost assumption, if there was a mistake,
is not a per se reason to reject a BART determination. Such a mistake
would help support disapproval of a cost analysis and resulting BART
determination only if it overstated costs in a material way and thus
tended to make a technology appear significantly more costly than it
actually would be.
If the State rejected SNCR based on an allegedly too-low cost of
urea, perhaps EPA could argue that the State was wrong in rejecting
SNCR. But EPA makes no such argument. It asserts only that its
consultant's urea price is different from the State's price. As
explained above respecting SNCR, to succeed in arguing that the State's
rejection of SNCR justifies disapproval of the State's BART, EPA would,
at a minimum, have to show that the State was arbitrary and capricious.
The choice of BART is the prerogative of the State, and the State is
charged with evaluating and balancing all five BART factors and
deciding how much weight to give to each factor. EPA may not disapprove
the State's judgment merely because it disagrees with the State on what
is a reasonable cost, or how the State balanced costs with other BART
factors. In fact, nothing in EPA's proposal takes issue with how
Wyoming weighed or balanced the BART factors, or with the State's
judgment regarding the terms of the settlement agreement on which the
State's BART determination for Laramie River was based. EPA's complaint
is not with the State's judgment in applying the BART factors. Rather,
it is that the State used information with which EPA disagrees. But
that cannot justify disapproval of the State's cost analysis or BART
determination.
Another commenter argued that the information EPA relied on to
conclude that urea market prices have increased is itself outdated,
noting that the report EPA cited as support for its urea price claim
was completed October 23, 2012, and relied on vendor emails from Fuel
Tech and PotashCorp dated October 12, 2012 and October 15, 2012,
respectively, to conclude that urea cost approximately $650 per ton.
The commenter pointed out that the same report recognizes that ``there
has been significant variability in [urea] cost,'' and added that since
the date of that report, urea prices have continued to vary
significantly, falling by roughly 50 percent.\215\ The commenter noted
that in its February 2013 revised cost analyses, EPA acknowledged the
beginning of the price decrease, pegging urea costs at $450 per ton.
The commenter added that urea prices are today far closer to Wyoming's
price assumptions than EPA's, which commenter stated were among the
highest prices for urea in the last four years. Therefore, the
commenter asserted, even if changes in commodity prices following SIP
submission were a valid basis for disapproving SIP analyses that relied
on prices at the time of SIP development, the EPA is factually mistaken
to claim that Wyoming unreasonably underestimated urea prices; rather,
the EPA has unreasonably overestimated urea prices by supporting its
analysis with an abnormally high price that is not reflective of the
current market.
---------------------------------------------------------------------------
\215\ Citing PotashCorp., Market Data, August 14, 2013, which
can be found at https://www.potashcorp.com/customers/markets/market_data/prices.
---------------------------------------------------------------------------
Response: We agree that a change in the market price of urea, in
and of itself, may have not provided EPA sufficient grounds for
rejecting the State's SNCR analysis. However, we identified a number of
deficiencies in our proposed rule, that when taken collectively, led
EPA to conclude that Wyoming's consideration of the costs of compliance
and visibility improvement for the EGUs was inadequate and did not
properly follow the requirements in the BART Guidelines and statutory
requirements. 78 FR 34748. Therefore, regardless of the market price of
urea, EPA would have reached the same conclusion.
Also, regardless of the cost of urea, EPA found material errors
with the State's cost analyses for SNCR that required that we revise
the analysis. In particular, as described in some detail in response to
other comments, the State significantly overestimated the ability of
SNCR to reduce NOX at Laramie River Station. There, the
State assumed that SNCR would reduce NOX by 48%. In response
to comments above, EPA has definitively established, using information
from a number sources, including Basin Electric's own consultant, as
well as a major SNCR supplier, that SNCR cannot approach this level of
control in the case of Laramie River Station. As such, it was
appropriate, if not obligatory, for EPA to revisit the SNCR analysis
for Laramie River Station.
Finally, today we are providing updated SNCR cost analyses in order
to address information provided by various commenters. Because we have
taken into consideration input from a number of commenters when
revising costs, we believe that they represent the most informed and
robust costs for SNCR presented yet. In particular, we have revised the
costs for Laramie River to reflect high furnace temperatures and low
reagent utilization (a factor not considered in Wyoming's analysis).
And we have also updated the SNCR costs to reflect the most recently
available cost of reagent as delivered to Wyoming. Our analyses are
consistent with our response on a similar comment in the Legal Section
of this final action.
Comment: EPA erroneously calculated urea costs. EPA made two
fundamental and significant errors that have the effect of overstating
the costs of SNCR, which in turn justified the EPA's conclusion that
SCR is cost effective. The errors are as follows:
EPA mistakenly converted pounds to tons in its calculation
of operation and maintenance costs for urea. See EPA's Revised Cost
Analyses for Jim Bridger Units 1-4--Detailed Spreadsheet Supporting
Analyses (NOX-SNCR tab, rows 62-64) (Bridger Costs); EPA's
Revised Cost Analyses for
[[Page 5163]]
Wyoming Sources--Detailed Spreadsheet Supporting Analyses
(NOX-SNCR--0 1--03 tab, rows 62-64) (EPA Costs). The cost
formula multiplies the urea rate (pounds/hour) times the cost (dollars/
ton) and divides that product by the source's megawatt rating to yield
a dollar per megawatt hour cost for urea. In converting pounds to tons,
EPA mistakenly divided by 1,000, when it should have divided by 2,000
(the number of pounds in a ton).
EPA incorrectly calculated the water dilution variable for
operation and maintenance costs in urea. See Bridger Costs
(NOX-SNCR tab, rows 62-64); EPA Costs (NOX-SNCR--
01--03 tab, rows 62-64). EPA's cost calculation incorporates the wrong
spreadsheet cell (auxiliary power cost). It should have instead
incorporated spreadsheet cell for the hourly water rate in thousands of
gallons per hour.
Response: The reagent cost calculation is correct. The urea rate
(assuming 100% urea) is multiplied by the cost for 50% by weight urea
and is multiplied by 2 (to account for the fact that the cost is for
50% by weight urea) and then divided by 2000 (for the tons to pounds
conversion). The effect is to divide by 1000, which is the equation
shown. Commenter is correct that there was an error in the dilution
water cost calculation. The error has been corrected in EPA's revised
cost estimates. The error has negligible impact on the estimated cost
of SNCR.
Comment: EPA asserts that it was an error for Wyoming to evaluate
SNCR using a controlled emission rate of 0.12 lb/MMBtu, which is about
a 48% reduction from 0.23 lb/MMBtu (the rate without new LNB and OFA).
78 FR 34748. EPA claims that after combustion controls reduce emissions
to 0.19 lb/MMBtu, SNCR can achieve only a 20% further reduction, to
0.15lb/MMBtu. Id., citing a Fuel Tech vendor report. EPA declined to
accept Wyoming's conclusion that SNCR would cut emissions by 20% to
30%. Id.
This conflicts with EPA's findings in the North Dakota FIP. 77 FR
20898. EPA found that SNCR plus LNB and SOFA at Coal Creek Station
Units 1 and 2 could reduce NOX from a baseline of 0.22 lb/
MMBtu to 0.115 lb/MMBtu, which is a 48% reduction. EPA explained that
after combustion controls reduced emissions to a degree, SNCR by itself
would cut emissions another 25%, despite the facility's claim that SNCR
would achieve only a 20% reduction. Id., citing a Fuel Tech report.
Response: EPA does not dispute that SNCR in combination with
combustion controls can reduce NOX by 48% in some cases. As
described in our response to other comments, EPA does not agree that
48% reduction of NOX is possible at Laramie River Station
using SNCR alone.
Comment: We agree with EPA that on an annual basis SCR can achieve
emission rates of 0.05 lb/MMBtu or lower. We recommend that EPA
consider that some coal-fired EGUs are achieving lower emissions; e.g.,
our search of the CAMD database found seven conventional coal-fired
EGUs averaging 0.04 lb/MMBtu or lower on an annual basis in 2012.
Unlike SNCR, for SCR the ability to achieve low NOX
emissions is less a function of boiler characteristics and more a
function of SCR design; it is generally accepted that SCR can reduce
NOX emissions by 80-90+%. However, the average control
efficiency assumed by EPA for all Wyoming EGUs was 75% (74% median
value).
The efficiency of NOX removal is determined primarily by
the amount of catalyst used, as pointed out by Hitachi in an email from
Hitachi to EPA Region 9 regarding SCR at the Navajo Generating Station.
In response to a question from the EPA on SCR NOX
performance guarantee, Hitachi replied that a 3 plus 1 SCR design could
be designed to guarantee NOX emissions of 0.05 lb/MMBtu on a
30-day rolling average. However, Hitachi also stated that the utility
and their engineer need to determine what margin needs to be applied to
insure the unit is capable of achieving less than the permit level on a
30-day rolling average. The EPA stated that in an engineering study
performed by Sargent & Lundy that with a NOX permit limit
between 0.07 and 0.08 lb/MMBtu, the SCR would be designed for 0.05 lb/
MMBtu. The difference between 0.05 and 0.07 is the margin necessary for
compliance. By underestimating the efficiency of SCR and potentially
overestimating the efficiency of SNCR, EPA has overestimated the
incremental costs for SCR.
Response: We agree with the information provided by the commenters
that SCR technology has, in some cases, the potential to achieve
emissions of less 0.05 lb/MMBtu (annual). However, emission limits
associated with BART do not need to meet the lowest emission rate
achieved with that technology at any coal-fired power plant. The RHR
provides that: ``The determination of BART must be based on an analysis
of the best system of continuous emission control technology available
and associated emission reductions achievable for each BART-eligible
source that is subject to BART.'' 40 CFR 51.308(e)(1)(ii)(A).
In determining the controlled emission level, EPA must consider
emission rates that are practically achievable in light of routine
variations in operation and understanding that the SCR must be designed
to maintain emissions below the required limit. SCRs in the U.S. are
typically either 2 plus 1, or 3 plus 1 systems, with two or three
initially full catalyst layers plus a spare layer for future catalyst
additions. EPA is not aware of, nor has commenter provided information
for, any 4 plus 1 SCR systems operating on coal-fired utility boilers.
Therefore, EPA would favor more commonly used 2 plus 1 or 3 plus 1 SCR
designs rather than the 4 plus 1 system described in commenter's
citation from Hitachi.
Additionally, the BART Guidelines state that: ``[i]n assessing the
capability of the control alternative, latitude exists to consider
special circumstances pertinent to the specific source under review, or
regarding the prior application of the control alternative'' (40 CFR
Part 51, Appendix Y, section IV.D.3) and that ``[t]o complete the BART
process, you must establish enforceable emission limits that reflect
the BART requirements''. (40 CFR Part 51, Appendix Y, section V). The
five-factor BART analysis described in the Guidelines is a case-by-case
analysis that considers site-specific factors in assessing the best
technology for continuous emission controls. After a technology is
determined as BART, the BART Guidelines require establishment of an
emission limit that reflects the BART requirements, but does not
specify that the emission limit must represent the maximum level of
control achieved by the technology selected as BART.
While the BART Guidelines and the RHR do not preclude selection of
the maximum level of control achieved by a given technology as BART,
the emission limit set to reflect BART must be determined based on a
consideration and weighting of the five statutory BART factors.
Therefore, limits set as BACT during PSD review, or emission rates
achieved from the operation of individual facilities under an emissions
trading program (e.g., CAA Interstate Rule) may provide important
information, but should not be construed to automatically represent the
most appropriate BART limit for a given technology.
As noted in our response to other comments, EPA does not believe
that we have overestimated the performance of SNCR, nor does EPA
believe that the performance of SCR has been underestimated.
[[Page 5164]]
Comment: EPA's errors in calculating SCR costs resulted in
significantly skewed cost-effectiveness determinations for every unit
analyzed. EPA overstated the costs per ton of SCR by between 33 and 99
percent. Although even EPA's cost estimates for SCR are within the
range that the EPA previously has found reasonable, the revised cost
analyses correcting what the commenter believes are EPA errors make it
clear that SCR is cost effective for every Wyoming EGU.
Response: Commenter's assertion that EPA's costs are too high is
largely based upon disagreement over the retrofit factors used, EPA's
inclusion of a provision for taxes and insurance, and disagreement with
use of 7% interest in determining the capital recovery factor. EPA has
responded to each of these issues in other comment responses and has
developed revised cost estimates that will incorporate changes where
EPA believes the changes are warranted.
Comment: Wyoming has overestimated the cost of SCR. Wyoming has not
provided justification or documentation for their cost estimates. We
(the commenter) were not provided with any vendor estimates or bids,
and Wyoming did not use the CCM, as recommended by the BART Guidelines.
For example, the cost estimates used by Wyoming and EPA contained
AFUDC, which is not allowed by the CCM and has been rejected by EPA
Region 8 in other analyses. As a result, total capital costs estimated
by Wyoming for SCR exceeded $300/kW at ten of the fifteen EGUs
evaluated. EPA has compiled a graphic presentation of SCR capital costs
adjusted to 2009 dollars. The EPA data confirm that SCR capital costs
typically range from $73-$243/kW. Wyoming has not demonstrated unique
features for the Wyoming EGUs that would justify cost estimates so much
higher than the range for the industry.
Response: We agree that in some cases Wyoming has overestimated the
cost of SCR. In order to address the cost analysis deficiencies noted
by the commenter, EPA has performed revised cost analyses for EGUs
where the cost of SCR is pertinent. In our revised cost analyses, we
have followed the structure of the CCM, though we have used the IPM
cost models to estimate direct capital costs and operating and
maintenance (O&M) costs.
3. Consideration of the Five Factors
Comment: We received numerous comments that the State followed the
requirements of the RHR and CAA, and simply did not come to the same
conclusions as EPA. Commenters stated that Wyoming's BART
determinations were based on a consideration of all five BART factors
and that the State weighed each factor appropriately.
Response: We disagree with this comment. As discussed in detail in
section VII.C.3.a of our proposed rulemaking, the EPA identified
numerous issues and errors with the State's cost analyses, including
the fact that the State underestimated the cost of SNCR and
overestimated the cost of SCR; the State overestimated the emission
reductions from SNCR; the State underestimated the control efficiency
of SCR; the State overestimated the capital costs for SCR; and the
State allowed for some costs not allowed by the CCM and thus their cost
analyses did not meet the requirements of the RHR. 78 FR 34748.
Likewise, for the visibility improvement modeling, EPA discussed in
detail in section VII.C.3.b of our proposed rulemaking why the State's
visibility modeling did not meet the requirements of the RHR (78 FR
34749). As stated in our proposed rulemaking, Wyoming did not consider
the visibility improvement associated with SNCR, which is clearly in
conflict with the requirements set forth in section 169A(g)(2) of the
CAA, as well as in the implementing regulations, which require that
states take into consideration ``the degree of improvement in
visibility which may reasonably be anticipated to result from the use
of such technology.'' In addition, it was not possible for EPA, or any
other party, to ascertain the visibility improvement that would result
from the installation of the various NOX control options
because Wyoming modeled the emission reductions for multiple pollutants
together in its SIP. Finally, Wyoming did not establish baseline
emission rates used for modeling in a manner consistent with BART
Guidelines. That is, Wyoming did not use ``the 24-hour average actual
emission rate from the highest emitting day of the meteorological
period modeled (for the pre-control scenario).'' 70 FR 39170. Instead,
Wyoming modeled baseline emission rates reflective of permitted
emission limits, leading to both an underestimation, and in some cases,
overestimation of visibility impacts.
Therefore, contrary to the commenters claim, today's action is the
result of Wyoming's failure to meet certain statutory and regulatory
requirements, and not a simple matter of the State and EPA arriving at
different conclusions.
Comment: Wyoming's BART NOX determinations for the
Naughton power plant further demonstrate Wyoming's consideration and
balancing of all five factors, including visibility improvement, and
its individualized consideration for each unit. For Naughton Units 1
and 2, Wyoming found that costs of compliance (total capital costs and
cost effectiveness), power losses (energy impacts) caused by post-
combustion NOX controls, environmental considerations
related to chemical reagents used with post-combustion NOX
controls (non-air quality environmental impacts), and visibility
improvement information indicated that LNBs and OFA are BART
NOX. However, for Naughton Unit 3, based upon its much
greater ``visibility improvement'', Wyoming determined that SCR is BART
NOX. Wyoming's BART NOX analyses across the
Naughton Plant's three units demonstrate Wyoming's consideration and
weighing of all five BART factors, including the decision to require
different levels of BART NOX controls across various units
at the same plant when Wyoming determined that the visibility
improvements and other factors at one unit justified more stringent
control. This example is yet one more indication, contrary to EPA's
assertions, that Wyoming did adequately consider ``visibility
improvement'' information in each of its BART determinations, including
Wyoming deciding in its discretion the ``weight and significance''
appropriate for each BART factor at each BART unit.
Response: We disagree with the commenter's assertion that the
State's determination for the Naughton units shows how the State
considered all five factors when the information that the State was
relying on was not accurate as pointed out in our response above.
Comment: PacifiCorp submitted its BART studies to Wyoming in 2007,
and the State completed its BART analyses during 2008. At that time the
remaining useful life of all PacifiCorp BART units was considered to be
at least 20 years. Primarily due to EPA's delays in dealing with the
Wyoming Regional Haze SIP, this assumed twenty-year life span is no
longer a valid basis for certain units. EPA now must take into account
the current useful life of the units, rather than the useful life
assumed under Wyoming's BART analyses completed at a different point in
time. Dave Johnston Unit 3's current depreciable life ends in 2027 and
the life for Naughton Units 1 and 2 ends in 2029.
As a practical matter, the SCRs required under the regional haze
FIP at Dave Johnston Unit 3 and Naughton Units 1 and 2 could not be
installed until shortly before the end of 2018, due to the regulatory
processes that apply to PacifiCorp's major investment
[[Page 5165]]
decisions, as well as the associated permitting and competitive
procurement timelines. At that time, the useful life for Dave Johnston
Unit 3 will be nine years, and for Naughton Unit 1 and 2 eleven years.
EPA must use these shorter useful lives in its BART analyses. Taking
into consideration the remaining useful lives of these particular BART
units clearly demonstrates that EPA's current assessed cost
effectiveness conclusions (whether using the Andover Report costs or
PacifiCorp's updated information) do not support the installation of
SCR on these units because they are not cost effective. To the extent
EPA needs to include firm retirement dates commensurate with the
depreciable lives for purposes of finalizing the regional haze FIP,
then PacifiCorp requests that EPA do so.
Response: We agree in part. However, because of our revised cost
and visibility analyses, and our conclusions regarding BART that stem
from those analyses, the comment is no longer pertinent to all of the
units in question.
Using a remaining useful life of 20 years, our revised analysis for
Naughton Unit 1 shows that the cost effectiveness of new LNBs with OFA
and SCR is $3,109/ton, while the incremental cost effectiveness is
$10,384/ton. The visibility improvement associated with new LNBs with
OFA and SCR is 0.33 deciviews. Similarly, using a remaining useful life
of 20 years, our revised analysis for Naughton Unit 2 shows that the
cost effectiveness of new LNBs with OFA and SCR is $2,566/ton, while
the incremental cost effectiveness is $8,440/ton. The visibility
improvement associated with new LNBs with OFA and SCR is 0.42
deciviews. Given these costs and visibility improvements, taken along
with the other BART factors, we no longer find that SCR is warranted
for Naughton Units 1 or 2, even assuming a longer remaining useful
life. Therefore, because the commenter suggested alternative control
options in lieu of the proposed SCR, which we would otherwise not
require, the comment is no longer pertinent to these two units.
However, as described below, it remains relevant to Dave Johnston Unit
3.
Using a remaining useful life of 20 years, our revised analysis for
Dave Johnston Unit 3 shows that the cost effectiveness of LNBs with OFA
and SCR is $2,635/ton, while the incremental cost effectiveness is
$7,583/ton. The visibility improvement associated with new LNBs with
OFA and SCR is 0.51 deciviews. Given these costs and visibility
improvement, taken along with the other BART factors, we continue to
find that SCR would be warranted for Dave Johnston Unit 3. However,
using a remaining useful life of 9 years, as identified by PacifiCorp,
our analysis shows that the cost effectiveness of LNBs with OFA and SCR
is $3,742/ton, while the incremental cost effectiveness is $11,781/ton.
Given the costs that result from the shorter remaining useful life,
along with other BART factors, we find that SCR is not warranted. As a
result, we find that combustion controls (LNBs) and an earlier
retirement date are BART for Dave Johnston Unit 3.
We note that depreciable life is the result of financial accounting
rules, such as for tax purposes, and is determined by capital
investments in the plant and associated accounting rules for the timing
of depreciation of those capital investments. As a result, the
depreciable life is often shorter than the economic life of the
facility. Economic life, which is the actual expected viable life of
the facility, is the key consideration in regard to the remaining
useful life (one of the five BART factors). As a result, depreciable
life is not relevant to a BART analysis unless the depreciable life
that results from a capital investment for BART is longer than the
economic life of the facility, in which case asset impairment charges
could result at the end of the economic life. Nonetheless, we
understand PacifiCorp's comment as meaning that, for financial reasons,
they would prefer to shutdown the units on an accelerated schedule in
lieu of installing SCR.
Finally, while PacifiCorp has presented revised cost information
along with their comments, we have not accepted these costs without
examination. As described in other responses, while allowing some of
the costs suggested by PacifiCorp, we have not allowed others. More
information regarding our cost analyses for the units in question can
be found in the cost report located in the docket.\216\
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\216\ Andover Technology Partners, ``Cost of NOX
Controls on Wyoming EGUs'', October 28, 2013; Wyoming EGU BART and
Reasonable Progress Costs--10/28/2013; Wyoming EGU BART and
Reasonable Progress Costs for Jim Bridger--10/28/2013.
---------------------------------------------------------------------------
Comment: In its proposed rule, the EPA found that the limits and
technologies mandated in the rule are cost effective based on
amortizing those costs over a 20 year period. Here, the Agency's cost
modeling is seriously flawed as many of the units subject to the new
rule have remaining lives significantly less than 20 years. For
example, Dave Johnston has a remaining life of only 14 years and
Naughton 16 years. Amortizing the larger investment required by the FIP
over these shorter lives would cause rates to go up even more, casting
doubt on the veracity of the EPA's conclusion that the FIP is cost
effective.
Response: See response above. We note, however, that we are using
the remaining useful life periods as presented by PacifiCorp in the
comment above for Dave Johnston Unit 3, which differ from this
commenter's numbers for remaining useful life.
Comment: We received comments that the State considered the energy
and non-air quality environmental impacts of compliance when developing
the State's plan. The commenters went on to say that it is not apparent
that EPA addressed the energy and non-air quality impacts in their
analyses.
Response: We disagree with this comment. Throughout our proposed
rulemaking, we consistently acknowledged that we are proposing to
accept the State's energy and non-air quality impacts analysis (e.g. 78
FR 34759). In the State analyses for all BART sources, it states that
the energy and non-air quality impacts do not preclude the selection of
any of the control technologies the evaluated for the BART sources. In
weighing all of the BART factors ourselves, we agree with this
conclusion and adopt it as our assessment of the energy and non-air
quality impacts.
Comment: There are three types of energy impacts that should be
considered. These include the energy associated with operating the
controls, the energy that must be provided when the unit is removed
from service in order to install the controls, and most importantly to
Wyoming and its citizens, the energy that must be replaced when the
emissions controls prescribed for a given unit are not economically
justifiable and result in accelerated unit retirements and
replacements.
The latter scenario is of particular concern because the EPA has
now proposed SCR controls for PacifiCorp's Naughton Unit 1, Naughton
Unit 2 and Dave Johnston Unit 3. Unlike the Wyoming SIP, the EPA's FIP
requires controls that are not expected to be justifiable and would
result in accelerated unit retirements and replacements, potential
natural gas conversions, and the associated costs and socio-economic
impacts of removing major coal-fueled generation resources from service
in areas of Wyoming that rely heavily on these facilities.
Response: The commenter raises concerns about energy impacts,
[[Page 5166]]
specifically: The energy associated with operating the controls, the
energy that must be replaced when the unit is taken out of service, and
the energy that must be supplied if the unit is retired in lieu of
addition of controls. The energy associated with operating the controls
are accounted for in the variable operating cost of SNCR and SCR. Most
of the construction occurs with the unit operating, but the unit must
be shut down when ductwork tie-ins are made to the SCR. Regarding
replacement energy when the unit is taken out of service, the
generation units have periodic outages of several weeks for major
maintenance items, such as turbine overhaul where there is adequate
time to make the tie-ins for the equipment. It is reasonable to assume
that facility owners would schedule outages for the SNCR or SCR
retrofits during periods when other maintenance is being performed that
requires the unit to be out of service, and this is what is commonly
done in practice. EPA has allowed five years after the final rule to
meet the emission limits, which should provide companies ample
opportunity to schedule retrofit activities during a normally scheduled
outage. As a result, retrofit of NOX controls would not have
a significant impact on the energy production of the generating unit.
As for the energy that must be replaced if a unit is retired, the
CAA and BART Guidelines do not explicitly require that this impact be
taken into consideration as part of the non-air quality and energy
impacts.
Comment: EPA's proposed approach is a myopic effort to focus on
only one portion of what is supposed to be a multi-faceted decision.
Appendix Y became law after notice-and-comment rulemaking, and states
are justified in relying on it when crafting their regional haze SIPs.
Indeed, EPA made clear that the Appendix Y guidelines ``are designed to
help States and others . . . determine the level of control technology
that represents BART for each source.''
BART determinations are composite decisions, with many facts and
data from each of the five BART factors playing a role in the ultimate
BART determination as decided by Wyoming. EPA's proposal to pluck out a
single BART factor (visibility improvement) as the sole justification
for rejecting Wyoming's entire NOX BART determination for
some units is arbitrary and capricious because it makes a single factor
more important than any of the others and also more important than the
composite BART determination as a whole. EPA's approach also disregards
each of the five BART factors as Wyoming evaluated them and ignores the
``weight and significance'' of each factor alone, and in combination
with the others, as Wyoming determined in its BART decisions.
Response: We disagree with this comment. The commenter is not
correct in asserting that EPA rejected the State's BART determinations
for certain sources based only on a single BART factor--visibility
improvement. EPA's rejection of the State's BART determination was
based on EPA's consideration of all five BART factors. Nowhere in our
notice do we indicate that we are rejecting the State's BART
determination based solely on the consideration of visibility
improvement. Moreover, as noted elsewhere in these responses to
comments, we found several instances in which the State's analyses were
inconsistent with the RHR and BART Guidelines, requiring that EPA
revise the State's analyses.
Comment: Use of the BART guidelines is only required for sources
located at electric generating facilities with a total capacity greater
than 750 megawatts. See 40 CFR 51.308(e)(ii)(B). Only three power
plants in Wyoming met these criteria: Basin Electric's Laramie River
Station, PacifiCorp's Jim Bridger, and PacifiCorp's Dave Johnston
plants. For consistency, and as a matter of State discretion, Wyoming
went above and beyond the requirements by following the five-step
process for all BART sources, not solely the three aforementioned large
electric generating facilities. EPA should commend Wyoming for taking
this approach, not use it as an excuse for invalidating the SIP.
Response: We agree that the BART guidelines are only mandatory
under the regional haze regulations for ``fossil-fuel fired power
plants having a total generating capacity greater than 750 megawatts.''
40 CFR 51.308(e)(1)(ii)(B). However, the fact that a state may deviate
from the guidelines for other BART sources does not mean that the state
has unfettered discretion to act unreasonably or inconsistently with
the CAA and our regulations. Where the BART guidelines are not
mandatory, a state must still meet the requirements of the CAA and our
regulations. In other words, the State must still adopt and apply the
best available retrofit technology, considering the statutory factors.
Comment: Based on the erroneous claims that the SIP incorrectly
analyzed costs, calculated baseline NOX emissions, and
modeled visibility improvement, EPA proposes a FIP for eight BART
sources in Wyoming. For each of these sources, EPA proposes to approve
all of the State's BART NOX analyses, except for the cost of
compliance, baseline emissions, and visibility factors. In other words,
EPA approves the State's analyses of some BART factors, but not the
others.
EPA, however, does not explain how it weighed the five BART factors
after substituting its cost of compliance, baseline emissions, and
visibility modeling for the State's. For example, for the Laramie River
Station units, EPA reiterates its disagreement with the State's
analyses and shows how its analyses change those factors. 78 FR 34776.
But EPA does not explain how it analyzed those new factor conclusions
in relation to the remaining Wyoming BART factors that EPA proposes to
approve. For each of the eight BART units, EPA takes the same approach,
failing to explain how it balanced the multiple BART factors.
Response: We disagree with this comment. As stated above, EPA came
to its conclusions on the State's BART determinations based on a
consideration of the five factors on an individual source basis. We
considered the visibility benefits and costs of control together by
weighing the costs in light of the predicted visibility improvement and
the other BART factors.
Comment: There are no threshold minimum acceptable cost
effectiveness levels, nor any requirements regarding how much weight a
state must give to cost factors versus other factors such as
visibility. EPA provides no explanation regarding what it views as a
reasonable cost factor, or why or how such a factor should be balanced
with visibility factors.
Response: See response above.
Comment: EPA must consider the energy that must be replaced when
the emissions controls prescribed for a given unit are not economically
justifiable and result in accelerated unit retirements and
replacements. This scenario is of particular concern because the EPA
has now proposed SCR controls for PacifiCorp's Naughton Unit 1,
Naughton Unit 2 and Dave Johnston Unit 3. Unlike the Wyoming SIP, the
EPA's FIP requires controls that are not expected to be justifiable and
would result in accelerated unit retirements and replacements,
potential natural gas conversions, and the associated costs and socio-
economic impacts of removing major coal-fueled generation resources
from service in areas of Wyoming that rely heavily on these facilities.
Response: As noted above, the CAA and BART Guidelines do not
explicitly require that these impacts be taken into
[[Page 5167]]
consideration as part of the non-air quality and energy impacts.
Comment: EPA's assertion that Wyoming underestimated the ability of
SCR to reduce NOX was arbitrary. The EPA cited no legal or
factual support for its assertion (at 78 FR 34748) that SCR can achieve
emission rates of 0.05 lb/MMBtu or lower on an annual basis. EPA
approved Colorado's use of a 0.07 lb/MMBtu annual emission rate for SCR
at coal-fired power plants because the EPA explained (at 77 FR 76871,
76873) that rate ``is within the range of actual emission rates
demonstrated at similar facilities in EPA's Clean Air Markets Division
(CAMD) emission database.'' EPA also said in that Colorado action that
an emission rate as low as 0.05 lb/MMBtu can be achieved only ``in some
cases[.]'' In its proposed disapproval of Wyoming's SIP, the EPA has
not explained why Wyoming's analyses are distinct from Colorado's.
Response: We disagree. In fact, the cost analyses submitted by both
PacifiCorp and Basin Electric in comments support EPA's assumption that
0.05 lb/MMBtu is achievable on an annual basis. PacifiCorp's comments
include a budgetary price estimate for three units from Babcock &
Wilcox indicating an outlet NOX rate of 0.04 lb/MMBtu.\217\
Though Babcock & Wilcox does not specify the averaging time basis of
this rate, because emission rates are lower over longer averaging
times, the emission rate would only be lower if not already expressed
on an annual basis. Similarly, the report prepared for Basin Electric
by Sargent & Lundy indicates an annual emission rate of 0.05 lb/MMBtu
for the Laramie River units.\218\ Therefore, it does not appear that
either Sargent & Lundy or Babcock & Wilcox dispute whether SCR is
capable of achieving an annual emission rate of 0.05 lb/MMBtu. In
addition, the commenter has not provided any information to
substantiate that SCR cannot achieve an actual annual emission rate of
0.05 lb/MMBtu.
---------------------------------------------------------------------------
\217\ Letter from Babcock & Wilcox Power Generation Group, Inc.,
to PacifiCorp Energy, page 3, August 19, 2013.
\218\ Laramie River Station SNCR and SCR Cost Estimates,
prepared for Basin Electric Power Cooperative by Sargent & Lundy,
Table 1, page 14, August 26, 2013.
---------------------------------------------------------------------------
Further, as noted by other commenters, information in the CAMD
database reveals that there a number of coal-fired EGUs retrofitted
with SCR which are achieving actual emissions of 0.05 lb/MMbtu or less
on an annual basis. It is important to note that the commenter is
questioning the annual emission rate achievable with SCR (0.05 lb/
MMBtu) that EPA assumed for the purpose of calculating cost
effectiveness. By contrast, when establishing a 30-day emission limit
for SCR, the annual rate must be adjusted upward to account for: (1) A
margin for compliance, (2) a shorter averaging period, and (3) start-up
and shutdown emissions. Therefore, EPA agrees that a 30-day rolling
average emission limit of 0.07 lb/MMBtu is appropriate for SCR. In
fact, we have approved this emission limit for Wyoming sources where
the State has required the installation of SCR. However, we continue to
find that it was appropriate for EPA to use the anticipated actual
annual emission rate, as opposed to the allowable 30-day limit, in
calculating cost effectiveness. The approach taken by EPA is consistent
with the BART Guidelines: In general, for the existing sources subject-
to-BART, you will estimate the anticipated annual emissions based upon
actual emissions from a baseline period. 70 FR 39167. That is, cost
effectiveness is more appropriately based on the reduction in annual
emissions, not the change in allowable emissions.
Finally, we disagree that we have treated Wyoming in a manner
distinct from Colorado with regard to the control effectiveness of SCR.
As noted by the commenter, in Colorado we held that SCR can achieve an
annual emission rate of 0.05 lb/MMBtu. However, in Colorado we also
held that it was unlikely that an analysis performed around this rate
would have altered the state's conclusions regarding BART. For units
where Colorado did require the installation of SCR (Craig Unit 2,
Hayden Units 1 and 2, and Pawnee), Colorado established a 30-day
rolling average emission limit of 0.07 to 0.08 lb/MMbtu. These emission
limits are commensurate with those established in Wyoming by both EPA
and the State for SCR.
4. Visibility Improvement
Comment: The implementation by EPA of its NOX FIP is an
overreach of its authority given the record in this case. In
particular, as it relates to the Laramie River Station, EPA arbitrarily
requires in its FIP the installation of SCRs to address regional haze.
However, the facts reveal that the installation of SCRs is not
justified because--even based on EPA's own calculations--the visibility
improvement that could be achieved is imperceptible. Nowhere in EPA's
proposed rule does it evaluate its FIP as achieving an improvement in
visibility at an individual Class I area that meets the standard
deciview definition, i.e., a full deciview being equal to the amount of
visibility improvement that is detectable by the human eye. In
addition, EPA failed in its analysis to consider the predicted change
in visibility between control options and whether the incremental
improvement for a given control is even perceptible. Conceding these
facts, the imposition of a FIP to achieve an imperceptible improvement
in visibility is arbitrary and capricious.
Response: We disagree that the visibility improvements for Laramie
River Station or other BART sources are de minimis or too small to just
justify the expense of requiring controls. The BART Guidelines are
clear that it is not necessary for the visibility improvement of a
particular control option to be above the perceptible threshold. 70 FR
39129.
Even though the visibility improvement from an individual source
may not be perceptible, it should still be considered in setting BART
because the contribution to haze may be significant relative to other
source contributions in the Class I area. Thus, we disagree that the
degree of improvement should be contingent upon perceptibility. Failing
to consider less-than-perceptible contributions to visibility
impairment would ignore the CAA's intent to have BART requirements
apply to sources that contribute to, as well as cause, such impairment.
The same facts apply to the commenter's assertions on incremental
visibility improvement.
In addition, we received numerous general comments that controls on
sources were not warranted because the visibility improvement was less
than the perceptible amount of 1.0 deciview, to which we respond in the
same way.
Comment: EPA's reliance on cumulative analysis of visibility
improvement is contrary to the CAA. The aggregate approach EPA is
employing in its proposed rule has been rejected by the D.C. Circuit.
The Court held that an EPA requirement for a group consideration of
visibility impacts was not allowed by the CAA. Instead, EPA must
consider all five BART factors for each source. As the Court explained,
with the cumulative approach, ``it is therefore entirely possible that
a source may be forced to spend millions of dollars for new technology
that will have no appreciable visibility improvement.''
Response: We disagree that our consideration of visibility
improvement was contrary to the CAA. Here the commenter has conflated
two separate issues related to cumulative visibility analyses. In the
D.C. Circuit ruling, American Corn Growers Ass'n v. EPA, 291 F.3d 1
(D.C. Cir. 2002), the issue was related to the cumulative visibility
[[Page 5168]]
impacts from multiple sources. There, the court held that a source may
be unduly required to install controls because of the emissions from
other sources. By contrast, in the instance related to our proposed
rule, the issue is related to the cumulative visibility impact to
multiple Class I areas from a single source. Therefore, there is no
relationship between the approach rejected by the D.C. Circuit Court
and that used in our assessment of visibility improvement.
Comment: EPA found that SCR provided only a 0.36 delta deciview
incremental visibility improvement for Dave Johnston Unit 3, using EPA
modeling, with an incremental cost of $7,163.00. 78 FR 34777-34778. EPA
failed to justify in its proposed rule how a 0.36 delta deciview
improvement, or approximately one-third that humanly detectible,
justifies the tremendous cost of SCR. Likewise, EPA found that
installing SNCR at Dave Johnston Unit 4 results in an incremental 0.11
delta deciview improvement. The alleged incremental visibility benefit
of installing SNCR at Wyodak is 0.12 delta deciview at an incremental
cost of $3,725. 78 FR 34784-85. EPA provides no justification for
requiring such tremendous costs for such an inconsequential visibility
improvement that likely falls within CALPUFF's margin of error. EPA's
modeling approaches are inconsistent because EPA has determined in
other states that visibility improvements greater than those used to
justify SNCR at Wyodak are too small or inconsequential to justify
additional pollution controls. See 77 FR 24794 (0.27 deciview
improvement termed ``small'' and did not justify additional pollution
controls in New York); 77 FR 11879, 11891 (0.043 to 0.16 delta deciview
improvements considered ``very small additional visibility
improvements'' that did not justify NOX controls in
Mississippi); 77 FR 18052, 18066 (agreeing with Colorado's
determination that ``low visibility improvement (under 0.2 delta
deciview)'' did not justify SCR for Comanche units). Tellingly, the
``low visibility improvements'' that Colorado found at the Comanche
units not to justify post-combustion NOX controls, as agreed
to by EPA, were 0.17 and 0.14 delta deciview. 77 FR 18066. In Montana,
where EPA issued a regional haze FIP directly, it found that a 0.18
delta deciview improvement to be a ``low visibility improvement'' that
``did not justify proposing additional controls'' for SO2 on
the source. 77 FR 23988, 24012. Here, EPA's actions requiring
additional NOX controls based on little-to-no additional
visibility improvement are arbitrary and capricious, especially when
EPA did not require additional NOX controls in other states
based on similar visibility improvements. This is particularly true in
Montana where EPA had direct responsibility for the regional haze
program.
Response: As stated elsewhere in our response to comments, we must
consider the five factors for each facility when making a BART
determination. Even though one factor (such as visibility improvement)
may be similar between two units, it must be weighed in the context of
the other BART factors. In addition, as we discuss in other response to
comments, in accordance with the BART Guidelines, controls may be
warranted even in instances where the visibility benefit is less than
perceptible.
We note that, in light of comments submitted during the public
comment period, we have revised our BART determinations for the
Naughton Units 1 and 2, the Dave Johnston Units 3 and 4, and Wyodak.
See sections III.B and V.D for a discussion on our consideration of the
BART factors and our BART determination for these units.
5. PM BART Determinations
Comment: We received comments that EPA's BART determinations with
respect to PM emissions from Wyoming EGUs are flawed. One commenter
pointed out that contrary to the BART guidelines, EPA failed to propose
BART limits on condensable PM and total PM (PM2.5 +
PM10), focusing instead solely on filterable PM. Commenters
went on to state that EPA underestimated the control effectiveness of
baghouses, which should be able to achieve a limit of 0.010 lb/MMBtu or
even lower, and thus EPA overestimated the costs effectiveness for
baghouses.
Response: We disagree with both points made in this comment. On the
first point, the BART Guidelines do not explicitly require that states
establish separate emission limits for condensable PM.\219\ However, we
do recognize, by merit of the compliance test methods specified for PM
(e.g. EPA Method 5B), that the BART emission limits in the Wyoming SIP
only pertain to filterable PM.
---------------------------------------------------------------------------
\219\ The BART Guidelines do not specify that States must
establish a BART limit for both PM10 and
PM2.5. The BART Guidelines provide the following: ``You
must look at SO2, NOX, and direct particulate
matter (PM) emissions in determining whether sources cause or
contribute to visibility impairment, including both PM10
and PM2.5.'' [Appendix Y to Part 51, section III.A.2.]
This language in the BART Guidelines was intended to clarify to
States that when determining whether a source is subject to BART,
the modeling evaluation to determine the source's impact on
visibility has to account for both PM10 and
PM2.5 emissions. There are several instances in which we
state in both the preamble to the RHR, and in the BART Guidelines
that PM10 may be used as indicator for PM2.5
in determining whether a source is subject to BART. Neither the RHR
nor the BART Guidelines specify that states must make separate BART
determinations for PM10 and PM2.5. Therefore,
we disagree that we must evaluate separate limits or disapprove the
PM BART determination for the Wyoming SIP on the basis that a BART
determination for PM2.5 was not made.
---------------------------------------------------------------------------
On the second point, the commenter has not provided any data or
information to substantiate that using a lower limit (i.e., 0.010 lb/
MMBtu) for baghouses would have changed the PM BART determinations.
Given that the cost effectiveness for baghouses was generally
excessively high, we do not expect that using a lower limit would have
changed the BART determination. Using Jim Bridger Unit 1 as an example,
an emission limit of 0.015 lb/MMBtu results in an emission reduction of
709 tpy, while using an emission limit of 0.010 lb/MMBtu results in an
emission reduction of 829 tpy (calculated in the same manner as in
Wyoming's BART determination: 6,000 MMBtu/hr heat input and 7,884 hours
of operation). In this example, the cost effectiveness of the new
polishing fabric filter was $8,980/ton, and the incremental cost
effectiveness was $16,396/ton. Given these costs, we have no reason to
conclude that such a modest difference in the reduction (120 tpy) would
lead to a meaningful improvement in visibility. This is particularly
true since, on a per unit mass basis, PM emissions have a lower
visibility impact than SO2 or NOX. A similar
conclusion can be drawn for other EGUs where baghouses were considered.
6. Incremental Costs and Visibility
Comment: Wyoming and EPA have placed undue weight on incremental
costs and incremental benefits. Wyoming and EPA have essentially based
their BART and reasonable progress determinations on incremental costs
and incremental benefits. (In almost every case, Wyoming stated that
the average cost-effectiveness of the proposed BART technologies for
NOX are all reasonable.) However, in discussing average and
incremental costs, EPA BART Guidelines explain: ``The average cost
(total annual cost/total annual emission reductions) for each may be
deemed to be reasonable. However, the incremental cost of the
additional emission reductions to be achieved may be very great. In
such an instance, it may be inappropriate to choose control B, based on
its high
[[Page 5169]]
incremental costs, even though its average cost may be considered
reasonable.'' Although EPA does not explain in its BART Guidelines what
it considers ``very great'' and ``high'' incremental costs, it goes on
to provide an example of how incremental cost is calculated, and
explains: ``The incremental cost of Option 1, then, is $20,000 per ton,
11 times the average cost of $1,900 per ton.''
The clear implication of EPA's advice in the BART Guidelines is
that incremental costs become a deciding factor only if they greatly
exceed average costs. Instead, EPA has determined that incremental
costs only twice the ``reasonable'' average costs are excessive. In
doing so, EPA ignores the established fact that pollution control costs
increase exponentially with control efficiency, which means that
incremental costs will always exceed average costs.
Response: We disagree with most aspects of this comment, but do
agree with the commenter that EPA has not defined what the terms ``very
great'' or ``high'' mean when pertaining to incremental costs. We do
not agree with the commenter that the one of the examples EPA provided
in 40 CFR part 51, Appendix Y, should be interpreted to mean that
incremental costs only become a deciding factor if they greatly exceed
average costs by some magnitude over twice the average costs. In
addition, incremental costs are to be considered within the context of
the five factors, including average cost effectiveness and visibility
improvement. Our BART determinations reflect the statement in the BART
Guidelines the commenter referenced in that while average cost
effectiveness may be reasonable, the EPA determined that the high
incremental costs in some instances made the selection of more
stringent controls not to be reasonable, when considered with
visibility improvement. We discuss in each instance our evaluation of
incremental and average costs and explain our conclusions.
Comment: Incremental visibility improvement is not mentioned in the
reasonable progress provisions or BART Guidelines, and EPA cannot
create a new criterion for the sole purpose of eliminating a control
option that is reasonably cost-effective and would yield a significant
visibility improvement. If EPA is going to compare costs and visibility
benefits, it must do so in a transparent and objective manner, and
state its criteria for acceptance or rejection of a control strategy.
Relatively subjective statements about costs being ``high'' or
visibility improvements ``small'' are not sufficient to justify the
decisions.
Response: We disagree with this comment. The RHR states ``When
making this determination [BART Step 5 on visibility impacts], you have
flexibility in setting absolute thresholds, target levels of
improvement, or de minimis levels since the deciview improvement must
be weighed among the five factors, and you are free to determine the
weight and significance to be assigned to each factor.'' 70 FR 39170.
EPA concludes that in exercising its discretion, a state or EPA may
consider the incremental degree of visibility improvement, which is a
part of visibility improvement. EPA's consideration of incremental
visibility improvement in our proposed action in Wyoming is also
consistent with EPA actions in other states (e.g., Kansas (76 FR
80754), Nebraska (77 FR 40150), and Oregon (76 FR 38997)). In comparing
control options and selecting one, it is natural to compare the
visibility improvement (that is, to compute the incremental visibility
improvement) for each option.
Comment: EPA in some cases rejected the best systems of continuous
emission reduction as BART based on a subjective judgment that the
incremental costs of concededly superior controls are not warranted by
the visibility benefits they yield. However, EPA has failed to offer
any rationale for these cost-benefit determinations, let alone the
increment threshold applied. As a result, EPA's conclusions are at odds
with the EPA's own analysis demonstrating that installing the most
effective controls will yield needed visibility improvements.
EPA's approach is inconsistent with the purpose of the RHR and the
five-factor BART analysis. The CAA identifies the elimination of human-
caused visibility impairment in Class I areas as the purpose and
required outcome of the haze program. 42 U.S.C. 7491(a)(1). Congress
directed states and the EPA to impose the best system of continuous
emission reduction on BART-subject sources, and identifies BART as the
feasible, cost-effective technology that produces the most visibility
benefits. For NOX emissions at Wyoming EGUs, EPA's source-
specific BART analyses uniformly point to SCR plus combustion controls
as the appropriate technology.
To avoid this result, however, EPA puts the technologies that it
has already determined are feasible and cost-effective through an
incremental benefit filter in which it assesses not just which control
technology makes the most visibility improvement, but how much more
progress it makes over the second best technology relative to their
costs. EPA applies this additional filter without disclosing what the
threshold of improvement over the next best technology or the ratio of
incremental improvement to incremental cost has to be, instead simply
declaring that ``the cost effectiveness value [of SCR] is significantly
higher than [inferior technology] and there is a comparatively small
incremental visibility improvement over the [inferior technology].''
If haze plans only compel installation of controls with lower
incremental costs and large incremental benefits (whatever those might
be), then it may be impossible to reach the goal of attaining natural
conditions in the Class I areas. This is especially true for Wyoming,
where there are many large pollutant sources affecting many Class I
areas. The level of visibility improvement that can be achieved through
reduction of emissions from any one source might always be deemed too
small to justify the cost of controls, in which case we will never be
able to eliminate that last increment of haze pollution because it is
too small to justify. While EPA or states may argue that additional
emissions reductions can be achieved in the future, the opportunity to
reduce haze-causing emissions in initial SIPs/FIPs by requiring BART,
as recognized and directed by Congress in the CAA, is the best chance
to make significant progress on this pervasive pollution problem. EPA's
use of the incremental benefit analysis to eliminate the best
pollution-reduction systems does not comply with the law.
Response: We do not agree with this comment. As stated above, EPA
based its decisions on the BART determinations based on a careful
weighing of the five factors, including average and incremental cost
effectiveness. Much like average cost effectiveness, EPA has not
established a threshold for incremental cost effectiveness as each BART
determination is an individual decision based on the five BART factors.
In accordance with the BART Guidelines, for each BART-eligible
facility, we considered incremental cost effectiveness, and when
weighed with the other BART factors, we reasonably concluded that more
or less stringent controls were not warranted.
7. Other Comments on BART
Comment: The majority of BART sources were constructed between 1962
and 1977. They have a typical life
[[Page 5170]]
expectancy of 50-60 years. They likely will be retired before 2064 and
replaced with state-of-the-art power generation technology and
pollution control equipment. This will be a major factor in achieving
the 2064 natural background goal for nitrate when these units are
replaced. Thus, there is no need for controls on these sources now.
Response: While the goal of the regional haze program is to achieve
natural visibility conditions in all mandatory Class I Federal areas by
2064, the statute explicitly calls for a program of reductions over
time, and incremental reasonable progress towards the long-term goal.
The requirement for states to implement BART applies during the first
planning period ending in 2018 and is the first increment of progress.
Furthermore, the remaining useful life of a facility is one of the five
factors considered for BART. Thus, for example, if a facility has made
a federally-enforceable commitment to either shut down or change fuels
by a date certain, the shortened useful life of the facility is
incorporated into the cost analysis as part of the amortization of
total capital costs.
Comment: Wyoming's SIP is silent with respect to BART emissions
limits during malfunctions and emergencies. However, EPA proposes a FIP
requirement that: ``These [BART] emission limitations shall apply at
all times, including startups, shutdowns, emergencies, and
malfunctions.'' 77 FR 33061. As EPA has previously noted, EPA's
proposed FIP requirement for Wyoming is not required by the RHR:
``Kansas' inclusion of the startup, shutdown, and malfunction
provisions as exemptions from the BART emission rates are not required
elements of the regional haze SIPs to be developed and submitted by
States pursuant to section 169 of the CAA.'' See 76 FR 52604, 52618.
EPA has also stated that ``EPA's disapproval of the startup, shutdown,
and malfunction provisions . . . does not trigger an obligation on the
part of EPA to issue a FIP pursuant to section 110(c) of the CAA, 42
U.S.C. 7410(c).'' Id.
Yet, EPA proposes to impose a FIP for startup, shutdown, emergency,
and malfunction emissions for Wyoming sources despite EPA's prior
statements that such exemptions do not trigger an EPA obligation to
issue a FIP. EPA's proposed action for Wyoming is arbitrary,
unauthorized and unlawful.
Wyoming does not agree with EPA's proposal to include emergencies
and malfunctions in 40 CFR 52.2636(c)(2). Permitted emission limits
should reflect the potential-to-emit (PTE) of a stationary source. The
PTE refers to a stationary source's maximum capacity to emit under its
physical and operational design. In estimating a source's PTE, Wyoming
has consistently only utilized emissions that are anticipated to occur
on a continuous or regular basis under the source's physical and
operational design. See United States v. Louisiana-Pacific Corp., 682
F. Supp. 1141, 1158 (D. Colo. 1988). Emissions that occur outside of a
source's physical and operational design or, are unplanned, are not
included in PTE estimates, and are addressed instead in accordance with
Wyoming's enforcement discretion. The Wyoming Supreme Court recently
upheld Wyoming's approach. See Sierra Club v. Wyoming Depart of Envtl.
Quality, 251 P.3d 310, 2011 WY 42 (Wyo. 2011). Therefore, Wyoming
requests that EPA withdraw its proposed FIP provision addressing
emergencies and malfunctions.
Response: We disagree with this comment. The RHR states that
``Section 302(k) of the CAA requires emissions limits such as BART to
be met on a continuous basis. Although this provision does not
necessarily require the use of continuous emissions monitoring, it is
important that sources employ techniques that ensure compliance on a
continuous basis.'' 70 FR 39172. The rule goes on to state that
``[m]onitoring requirements generally applicable to sources, including
those that are subject to BART, are governed by other regulations.''
See, e.g., 40 CFR part 64 (compliance assurance monitoring); 40 CFR
70.6(a)(3) (periodic monitoring); 40 CFR 70.6(c)(1) (sufficiency
monitoring) (70 FR 39172). Therefore, it is clear that the rule
intended for BART emission limits to be met on a continuous basis and
did not provide either explicitly or implicitly exceptions for startup,
shutdown, or malfunction. Furthermore, it has been EPA's longstanding
position that SIP provisions generally cannot contain automatic
exemptions for startup, shutdown, and malfunction.\220\ With respect to
PTE, the comment does not identify how the arguments about PTE are
relevant to a BART emissions limit. Finally, regarding claims of
inconsistency with the final action for Kansas, commenter quotes from
the proposed not the final agency action. As explained in the final
agency action, EPA did not take final action on those portions of the
Kansas submittal, the state withdrew them.\221\
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\220\ See for example, EPA's September 20, 1999, guidance,
``State Implementation Plans: Policy Regarding Excess Emissions
during Malfunctions, Startup and Shutdown,'' cited in the next
footnote.
\221\ As EPA Region 7 explained in their final action 76 FR
80754, 80755-6 (Dec. 27, 2011): ``As EPA explained in the proposed
notice, the Consent Agreements exempted periods of startup and
shutdown for both Kansas City Power and Light and Westar Energy from
compliance with applicable emission limits, which were not narrowly
defined, and exempted periods of malfunction for Westar Energy. EPA
proposed to disapprove the exemptions because they are inconsistent
with the Clean Air Act and EPA's September 20, 1999, guidance,
``State Implementation Plans: Policy Regarding Excess Emissions
during Malfunctions, Startup and Shutdown.'' Steven Herman,
Assistant Administrator for Enforcement and Compliance Assurance,
and Robert Perciasepe, Assistant Administrator for Air and
Radiation, ``State Implementation Plans (SIPs): Policy Regarding
Excess Emissions During Malfunctions, Startup, and Shutdown,''
September 20, 1999; and 52 FR (45109 November 24, 1987).
EPA subsequently received a letter from the State dated December
1, 2011, withdrawing the SSM provisions in the Consent Agreements in
their entirety from the regional haze SIP. Specifically, the
following four provisions were withdrawn from EPA's consideration
for approval in the regional haze SIP:
1. All references to, ``excluding periods of startup and
shutdown'' in Paragraph 23 of the Kansas City Power and Light
Company regional haze agreement;
2. The reference to, ``excluding periods of startup, shutdown
and malfunction'' in footnote 1 of Appendix A to the Westar Energy,
Inc. regional haze agreement;
3. All references to, ``excluding periods of startup and
shutdown'' in Chapter 9.3.1 of the Kansas regional haze SIP;
4. And the sentence, ``The Agreements between KDHE and the
affected BART sources currently exclude emissions associated with
startup, shutdowns, and malfunctions (SSM) in the agreed upon
emission limits'' in Chapter 9.5 of the Kansas regional haze SIP.
Since the SSM provisions were withdrawn by the State, and are
therefore no longer before EPA, neither EPA's proposed disapproval
of these exemptions, nor the comments on that proposed disapproval,
are relevant to this final action.
---------------------------------------------------------------------------
Comment: The EPA's proposed FIP states only that subject-to-BART
sources must comply within five years of adoption of the FIP. This
blanket schedule of compliance for FIP sources is contrary to the CAA.
For one thing, by its very language, the EPA's proposed FIP fails to
ensure that subject-to-BART sources ``procure, install, and operate, as
expeditiously as practicable'' any additional controls that may
represent BART as required by the CAA. See 42 U.S.C. 7491(b)(2)(A) and
(g)(4). The EPA only requires that sources comply within five years,
but does not actually require sources to comply with BART limits
established in the FIP ``as expeditiously as practicable.'' Thus, EPA's
proposed FIP fails to implement the statute. Furthermore, simply
stating verbatim in the FIP that ``sources shall comply with the
emission limitations and other requirements of this section within five
years of the effective date of this rule'' fails to give force and
effect to the statutory requirements that
[[Page 5171]]
compliance occur as ``expeditiously as practicable.'' Here, the CAA is
clear that in mandating ``expeditious'' compliance, FIPs must ensure
that subject-to-BART sources comply as soon as possible. In this case,
the EPA's proposed FIP simply fails to ensure compliance with BART as
soon as possible. It lacks any concrete dates by which subject-to-BART
sources must comply, other than to state that sources must comply
within the statutory maximum compliance date of five years.
However, the CAA is clear that if a source can comply with BART
before five years, it must comply by that earlier date. See 42 U.S.C.
7491(g)(4). Simply deferring to the five-year deadline undermines the
Congressional intent behind the ``as expeditiously as practicable''
provision. It is notable that the EPA actually required ``expeditious
compliance'' for Jim Bridger Units 3 and 4.
Response: We have reviewed the compliance dates for meeting BART
limits that are contained in the SIP. Given the magnitude of the
retrofits being undertaken, we believe that five years from the
effective date of this final rule is as expeditiously as practicable.
We note that our compliance dates for Jim Bridger Units 3 and 4 are
based on the fact that those are the dates in the State's SIP which we
are approving for these two units.
Comment: Compliance with the perceived dictates of the CAA need not
be as inflexible as contemplated in the EPA's proposal. By exploring
and employing creative solutions, it is possible to reduce emissions to
satisfy the CAA while ensuring reasonable value and more cost-effective
expenditures for PacifiCorp's ratepayers. Two recent examples of
successful creative alternatives that will save ratepayers many
millions of dollars include the recent proposals of (1) Public Service
of New Mexico for its San Juan Generating Station, and (2) PacifiCorp
regarding its Naughton Unit 3 in Wyoming.
Notably, the EPA's revised 2013 proposal for Wyoming implicates ten
of PacifiCorp's coal-fueled units. Given the number of affected
PacifiCorp generation plants, Wyoming appears to be a particularly
fertile ground for encouraging the type of alternative solution that
satisfied the CAA with regard to San Juan and Naughton Unit 3. We urge
the EPA, in response to these comments, to signal its willingness to
consider all feasible compliance options that PacifiCorp may offer
(including those that the EPA has no authority to order) to provide the
lowest-cost solution for ratepayers in achieving emissions reductions.
Response: We agree with the commenter's points that there is some
flexibility under the CAA to meet the requirements of the RHR. As with
past actions, EPA is willing to consider alternatives compliance
proposals that are put forth.
Comment: Wyoming's regional haze program has been underway for
several years. Under EPA's RHR, BART controls were expected to be
installed by the end of 2013. Wyoming appropriately and effectively
developed and implemented a regional haze program that met the 2013
timeline. As required by the Wyoming SIP, and with the one exception of
Naughton Unit 3 which has a deadline of 2014, PacifiCorp has fully
implemented Wyoming's BART requirements for its Wyoming BART units. As
a result, in 2013 alone, there will be 76,000 fewer tons of visibility
impairing pollutants emitted by PacifiCorp BART units than was emitted
in 2004.
Had Wyoming waited for EPA's final FIP, none of these reductions
would have occurred to date. In other words, the Wyoming SIP required
regional haze reductions to begin earlier and extend over a longer
period of time than EPA's FIP. It is striking to note that from 2005-
2021 the State's regional haze program will have removed 243,000 tons
more NOX from PacifiCorp's Wyoming facilities than EPA's
proposed FIP.
In 2022, the EPA's FIP begins providing an annual benefit of 5,100
tons per year. Ironically this benefit only lasts for six years, when
the units at which EPA's proposed FIP requires more stringent controls
are retired. By 2027, the Wyoming Regional Haze SIP will have removed
over 210,000 more tons of NOX from PacifiCorp's units than
the EPA's proposed FIP, with a significantly lower cost (more than $300
million less in capital) and will require significantly lower
expenditures in operation and maintenance between 2022 and 2027.
Response: We acknowledge that the emission reductions already
achieved by PacifiCorp's Wyoming facilities are substantial. However,
the emission reductions already achieved at the PacifiCorp facilities
do not release EPA from its obligation under the CAA to review
Wyoming's SIP, or to promulgate a FIP where we find that the SIP fails
to comply with the CAA or RHR.
We disagree that the SIP will result in greater emission reductions
than the FIP. As discussed in section III.B, in response to comments
received during the public comment period, we have made several changes
to our proposed BART determinations for the PacifiCorp units. Even so,
our final rule today continues to achieve greater emission reductions
than the Wyoming SIP for the PacifiCorp units. For Wyodak, our BART
determination (new LNBs with OFA and SCR) results in an additional
2,496 tons per year when compared to the SIP. For Dave Johnston Unit 3,
though PacifiCorp has the option to shut down the unit in 2027, our
BART determination (new LNBs with OFA and SCR) results in an additional
1,597 tons per year when compared to SIP. Clearly, even though we are
no longer requiring some of the BART controls which we proposed, the
FIP achieves greater emission reductions than the SIP at any point in
time. Regardless, the BART determination for any BART source is founded
on a consideration of the statutory BART factors, and not a comparison
of overall reductions achieved between a federal and state plan.
D. BART Sources
1. Basin Electric Laramie River Station Units 1-3
a. General Comments
Comment: We received numerous comments expressing concern over the
economic impact our proposed FIP would have for customers of Basin
Electric, and the commenters urged us to approve the State's regional
haze SIP. The commenters went on to point out that Basin Electric is a
non-profit electric cooperative that must pass costs on directly to
consumers. One commenter noted that the projected cost to install SCR
for each of the three units at Laramie River will be $200 million for
Western Minnesota and Missouri Energy Services members. If that cost is
spread over a 10-year period, the cost would be $110 million a year,
which relates to an increase in electric rates of 8 percent.
Response: In considering the costs of compliance, the BART
Guidelines instruct states and EPA to evaluate several metrics,
focusing specifically on average cost-effectiveness and incremental
cost-effectiveness, not total capital cost or total annual cost. EPA
has found that the average and incremental cost-effectiveness of SCR is
reasonable for all three units at Laramie River. While the BART
Guidelines suggest that total capital cost and total annual cost, as
well as incidental increases in prices to consumers, can be considered
as part of an affordability demonstration, Basin Electric did not
provide the necessary detailed information to suggest that installing
SCR at Laramie River would be
[[Page 5172]]
unaffordable, either for the cooperative or its rate payers.
Consequently, we believe that our analysis of the costs of control,
which focused on cost-effectiveness, was appropriate.
Comment: We received numerous comments that EPA's FIP would result
in additional costs of $600-$700 million for the owners of Laramie
River Station with no perceptible visibility improvement.
Response: See the response above. We have addressed the issue of
perceptible visibility improvement in section V.C.4. As explained in
the introductory section and elsewhere, the visibility improvements
from controls at Laramie River are significant, even when considered on
a unit by unit basis.
b. NOX BART Determination
Comment: One commenter provided a spreadsheet with cost
calculations for each of the affected Laramie River units.
Response: EPA has reviewed the spreadsheet.\222\ The major
difference in calculations relates to selection of retrofit factor and
cost of property taxes and insurance (excluded by commenter). Commenter
indicates that all facilities have a retrofit difficulty of 1.0. EPA
disagrees and has provided our reasons for retrofit factors in other
comments. In addition, for certain units where we have incorporated new
cost information submitted by the facility owner's during the comment
period, we are no longer applying a retrofit factor. Finally, property
taxes and insurance costs should be included, but only to the extent
that they are actually realized. See details in the cost report
included in the docket.\223\
---------------------------------------------------------------------------
\222\ Wyoming EGU BART and Reasonable Progress Costs--10/2013.
\223\ Andover Technology Partners, ``Cost of NOX
Controls on Wyoming EGUs'', October 28, 2013.
---------------------------------------------------------------------------
Comment: EPA's decision to change its initial NOX BART
proposal for Laramie River Station Units 1-3 from SNCR to instead
propose requiring SCR is well-supported by EPA's analysis. When site-
specific information is appropriately considered, the costs of SCR at
Laramie River Station are even lower than EPA estimated. EPA used a
``social interest rate'' of 7 percent in its analysis when the plant's
owner used an interest rate of only 6 percent; the EPA accepted the
owner's claimed costs of new LNBs with OFA (after subtracting
disallowed costs), even though other data submitted by the company
demonstrated lower costs for these combustion controls; and the EPA's
cost estimates assumed unreasonably high auxiliary power costs of
$0.06/kilowatt hour (``kWhr''), when even the owner assumed an
auxiliary power cost of $0.015/kWhr in its cost-effectiveness analyses.
Making the suggested cost changes to the analysis would result in cost
effectiveness values ranging from $3,244/ton to $3,532/ton, as opposed
to the EPA's values ranging from $3,589/ton to $3,903/ton. The
substantial visibility benefits afforded by SCR on Laramie River Units
1-3 also justify a finding that SCR is BART on these units. The costs
and visibility improvements are consistent with what other states in
their SIP or EPA in a FIP have found reasonable for BART controls.
Response: EPA has addressed each of the issues raised by the
commenter in other responses. EPA has provided revised cost estimates
based upon input and consideration of all commenters.
Comment: The Sargent & Lundy Evaluation demonstrates that the costs
of installing SCR at Laramie River Station are excessive and supports
Wyoming's determination that OFA plus LNB constitutes BART. In response
to EPA's proposed SIP disapproval and FIP, Basin Electric requested
that Sargent & Lundy prepare detailed and site-specific cost estimates
for installation and operation of SNCR and SCR at the Laramie River
Station. Sargent & Lundy, ``SNCR and SCR Cost Estimates, Laramie River
Station'' (August 26, 2013) (S&L Evaluation). Sargent & Lundy is a
leading engineering, design, and consulting firm and a system supplier
that has extensive experience with the specification, evaluation,
selection, and implementation of emission control technologies and
coal-fired power plants, including more than 98 projects for the
control of NOX emissions. S&L Evaluation section 2. Indeed,
Sargent & Lundy has participated in the installation of more than 72
SCR systems and 26 SNCR systems. Id. The Sargent & Lundy Evaluation
follows the BART Guidelines and uses the methodology in the CCM where
possible, while addressing site-specific variables that are critical to
reaching an accurate cost estimate for these NOX control
technologies at Laramie River Station.
The Sargent & Lundy Evaluation estimates that the total capital
costs of SCR would exceed $746 million, while annual costs of an SCR
system for the Laramie River units would total more than $86 million.
S&L Evaluation, Tables 3, 7. Total capital costs for installing SNCR on
all three units, on the other hand, would be approximately $50.6
million with annual costs of approximately $20 million. Id. Tables 2,
6. Moreover, the cost effectiveness of SNCR based on the Sargent &
Lundy Evaluation would be between $6,967 to $7,013 per ton of
NOX removed. Cost effectiveness values for SCR range from
$8,531 per ton of NOX removed to $9,048 per ton of
NOX removed, with an incremental cost effectiveness compared
to SNCR of between $9,157 per ton to $9,862 per ton. Id. Table 7. The
Sargent & Lundy Evaluation demonstrates that the costs of installing
SCR at Laramie River Station are excessive and supports Wyoming's
determination that OFA plus LNB constitutes BART.
Response: As noted on page 21 of Exhibit 14 of Basin Electric's
comments: ``. . . Cost estimates prepared for Laramie River Station are
based on equipment costs and budgetary quotes available from similar
projects and Sargent & Lundy's experience with the design and
installation of retrofit SNCR and SCR control systems. The Laramie
River Station cost estimates are conceptual in nature; thus, Sargent
and Lundy did not procure equipment quotes specifically for the Laramie
River Station control systems. Rather, equipment costs for the Laramie
River Station projects are based on conceptual designs developed for
the control systems, preliminary equipment sizing developed for the
major pieces of equipment, and recent pricing for similar equipment . .
.''
As noted in EPA's response to other comments, EPA has found a
number of deficiencies in Sargent & Lundy's estimates and disagrees
with the costs they have arrived at for SCR. Also as described in
response to other comments, in light of recently submitted information,
EPA has accepted Basin Electric's estimated capital cost of SNCR.
Comment: The Sargent & Lundy Evaluation and resulting cost estimate
is far more accurate than the study level estimate contemplated by the
CCM and the IPM algorithms relied upon by EPA in its SIP disapproval
and FIP. The Sargent & Lundy Evaluation takes into consideration site-
specific design and operating parameters and provides a conceptual, or
scoping-level, estimate for SNCR and SCR at Laramie River. S&L
Evaluation section 4.5.
The BART Guidelines state that ``cost estimates should be based on
the OAQPS Control Cost Manual, where possible'' and in those cases
where the CCM addresses the control technology in ``sufficient detail
for a BART analysis.'' 70 FR 39166. In all cases, however, ``[t]he cost
analysis should also take into account any site-specific design or
other conditions . . . that affect the cost of a particular BART
technology option.'' Id. The CCM
[[Page 5173]]
describes various technologies and provides general costing
methodology, but EPA acknowledges that the methodology is intended to
provide a ``rough order of magnitude'' estimate of costs that is
accurate to within 30%. CCM section 1.2, page 1-4. This
rough estimate is appropriate for regulatory development because it can
be prepared at a ``relatively low cost with minimum data.'' Id. section
2.2, page 2-3 (internal quotations omitted). See also S&L Evaluation at
section 4.5. But ``EPA does not claim cost estimates for industry at
greater than study level accuracy for industrial users'' because ``the
industrial user will necessarily have much more detailed information
than the generic cost and sizing information.'' CCM section 2.2, page
2-4, 2-5.
The BART Guidelines may reference the CCM because it provides a
simple and less costly methodology for estimating costs, but neither
the Guidelines nor the CCM require use of a less accurate methodology
where more accurate methodologies are appropriate. Indeed, the BART
Guidelines require consideration of site-specific variables that in
some cases, such as with SCR, are not factored into the examples
provided by the CCM. 70 FR 39166. Under these circumstances, the Manual
``offers the user an opportunity for greater accuracy than that used by
regulators'' and gives users the discretion to ``exercise `engineering
judgment' on those occasions when the procedures need to be modified or
disregarded.'' CCM section 1.2, page 2-4, section 1.3, page 1-7.
The cost estimates prepared by Sargent & Lundy are scoping-level
estimates, which required the use of numerous site-specific design
parameters that are not included in the general CCM equations and
reflect all costs to install the control systems, taking into account
site-specific variables and physical constraints. S&L Evaluation
section 4.5, Attachments A1, A2. These estimates are far more accurate
than EPA's estimates, reinforce Wyoming's BART determination, and
demonstrate there is no basis for EPA to disapprove the State's action.
Response: We agree that source-specific costs can be useful in the
BART analysis and agree with a number of the cost estimates in the
Sargent & Lundy analysis. However, as noted in our response to other
comments, EPA found Sargent & Lundy's estimates of SCR capital cost
deficient in a number of respects, specifically: (1) Inadequate
explanation for the high labor rates that were assumed when compared to
published labor rates; (2) High overtime and per diem costs without
sufficient explanation; (3) Apparent duplication of costs associated
with General Facilities; (4) Inclusion of AFUDC; (5) Apparent
duplication of contingencies and other cost adders; and (6) Addition of
unnecessary SO3 mitigation system. All of these contributed
to excessively high capital cost. Sargent & Lundy also assumed
excessively high cost for replacement catalyst, which contributes to
high operating cost.
As described in our responses to other comments, in light of
recently submitted information, EPA has accepted Basin Electric's
estimated capital cost of SNCR.
Comment: The Sargent & Lundy's estimate for SCR considers critical
site-specific variables that are not captured by the CCM. The Sargent &
Lundy estimate for SCR is based on an in-depth, detailed study of site-
specific costs conducted by a team of engineers with extensive
experience in SCR installations. In order to establish SCR control
system design parameters and to prepare inputs for the capital cost
estimate, Sargent & Lundy engineers performed a site walkdown to
identify site constraints for the SCRs and associated plant
modifications and reviewed operating conditions at Units 1 through 3
affecting flue gas conditions at the SCR inlet. Sargent & Lundy then
developed general arrangement drawings for the SCRs and new ductwork,
on which estimations for material quantities were made. Finally,
Sargent & Lundy evaluated the existing forced draft (FD) fan buildings
to determine whether the existing buildings could support the SCR
structures based on the conceptual design.
Sargent & Lundy's evaluation identified important design
considerations affecting the SCR cost estimates, many of them directly
related to the considerations that EPA acknowledges in the CCM make
broad brush cost estimates for SCR nearly impossible. CCM section
2.5.4.2, page 2-28 (installation of SCR can ``impose an addition
expense to `shoe-horn' the equipment into the right locations'' where
``there is generally little room for the reactor to fit in the existing
space and additional ductwork, fans, and flue gas heaters may be needed
to make the system work properly.''). The considerations include, inter
alia, congested existing plant configuration, and limited auxiliary
power available at the station. S&L Evaluation section 4.3.1.
The site congestion at Laramie River Station substantially
complicates installation of SCR systems because the location of the FD
fan buildings limits the open area available to drop support columns
for the SCR. Id. Based on the site walkdown and review of drawings
provided by Basin Electric, the conceptual design placed the SCRs
directly above the existing FD fan buildings, which will require that
the SCR support columns penetrate the FD fan buildings. This, in turn,
would require the construction of deep foundations for the SCR support
columns in a congested area resulting in challenging and time-consuming
efforts to ensure adequate support. Id. Another related complicating
factor relates to constructability issues. All three units are
constructed side-by-side in a row with little space between them, which
limits crane placement and would require selection of larger, more
expensive cranes during installation. Id. Another major design
consideration identified by Sargent & Lundy is the need for entirely
new auxiliary power equipment for the SCR and replacement induced draft
(ID) fans because the existing ID fans currently are running at full
capacity. Id.
In addition, Sargent & Lundy's Evaluation took into consideration,
among other factors, the following site-specific conditions that affect
the cost of SCR at Laramie River Station: (1) Boiler Building
Reinforcement. SCR duct work will penetrate the existing boiler
building structural columns, thereby requiring that the boiler building
structural supports be redesigned and rebuilt and engineered to ensure
continued support of the 20-story boiler building. (2) SCR Reactors and
Catalyst. The conceptual design calls for two reactors per unit using
anhydrous ammonia as the reagent. To achieve required NOX
emission reductions on a consistent basis, three layers of catalyst
would be required and the SCRs would need to be designed to hold four
layers of catalyst. (3) Ammonia System. The conceptual design located
the anhydrous ammonia system in a remote location from the units and,
therefore, the cost estimate assumed that all three SCR units would
share a single ammonia storage facility. (4) Structural Stiffening.
Structural stiffening of the ductwork and equipment downstream of the
boiler and upstream of the new ID fans would be required by federal
regulation to operate at more negative pressures due to installation of
the SCR.
Response: EPA has reviewed the submitted comments, and believes
that for each of the items cited, insufficient information was provided
to justify why the cost of SCR at Laramie River Station would be so
much higher than for other SCRs. Commenter cites the location of the
SCR reactor as an issue. This is an
[[Page 5174]]
issue that is common to every SCR retrofit. Based upon information used
by EPA and information submitted by Basin Electric, there is no
indication that location of the SCR reactor will be any more difficult
than at any other site. In fact, the location is a rather common
location. There was no indication that major equipment would need to be
relocated. Therefore, in this respect Laramie River does not appear to
be any more difficult than a typical SCR retrofit.
Pertaining to site congestion, Laramie River is no more congested
than a typical facility that retrofits SCR, and in some respects is
less congested. There is greater difficulty in retrofitting unit 2 (the
middle unit), and EPA accounted for that with a higher retrofit
difficulty factor. Commenter indicates that the SCR support steel will
interfere with equipment at the ground level, specifically, the FD fan
buildings, requiring installation of steel and deep foundations in a
congested area. SCRs are rarely installed at ground level and are
normally installed above other equipment. SCR support steel is
therefore commonly installed in this area below the SCR and there
typically is other equipment that interferes with this. This is not an
unusual situation and is not a reason for SCR cost at Laramie River
Station to be higher than a typical retrofit. Side-by-side installation
is common, and EPA has accounted for that with a higher retrofit
difficulty factor for unit 2.
Most boilers are inside a boiler building and SCRs are always built
outside the boiler building, making it always necessary to route
ductwork through the boiler building wall or through the roof. Making
penetrations for SCR ductwork through the boiler building wall is very
common in SCR retrofits, and this is not a reason to justify a higher
cost for an SCR retrofit at Laramie River station. SCR reactor 3 plus 1
and in two sections is a common SCR arrangement for a boiler of this
size and does not justify a higher than average cost for Laramie River.
All SCR systems have ammonia storage facilities and typically try to
combine storage for all units at a site together. Ammonia storage is
not a major cost item and where the system is located on the site will
not make a large difference in overall cost. Pertaining to the need for
an additional fan, the cost estimate used by EPA had a specific line
item cost for the fan and associated costs for electrical and other
modifications. Structural stiffening of ductwork is typically required
when an ID fan is added. The cost estimate by EPA included provision
for this. Notwithstanding these points, EPA has accepted parts of Basin
Electric's cost estimate where those costs are supported. See EPA's
response to other comments for more information.
Comment: Sargent & Lundy estimated capital costs based on the
conceptual design of SCR installation at Laramie River Station and in-
depth itemized studies, not the type of generic cost factors set forth
in the CCM. As a result, the Sargent & Lundy Evaluation provides cost
estimates that reflect more accurately the actual costs Basin Electric
would incur for installation of SCR at Laramie River.
The Sargent & Lundy Evaluation uses an SCR design with itemized
budgetary cost estimates for major equipment items and site-specific
costs. S&L Evaluation section 4.5, Attachment A2. For example, the
estimate includes line-item costs for upgrades, replacements, or
installations of the following plant subsystems to support SCR
operation at the Laramie River Station: (1) Foundation work to support
SCR systems; (2) Economizer ductwork modifications; (3) Larger ID fans
will be required on all three units, requiring replacement of the
existing ID fans; (4) Existing electrical systems are not capable of
handling the new fan loads and SCR control systems and will require
significant upgrades; (5) Structural stiffening of the duct work
downstream of the air heater and upstream of the new ID fans; (6) The
existing Distributed Control System needs to be expanded; (7) Dry
sorbent injection control systems will be required on Units 1 and 2 for
SO3 mitigation, resulting from the wet scrubbers installed
on those units; and (8) Ammonia unloading area construction, including
two storage tanks and tank equipment, as well as ammonia delivery and
vaporization equipment.
Because of the site-specific nature of these items, the assumptions
in the CCM would not be adequate to account for them, yet these types
of system upgrades add substantial cost to the SCR installation.
Sargent & Lundy prepared direct capital cost estimates for each of
these systems, including all costs associated with equipment, labor,
and freight. S&L Evaluation section 4.5. As EPA acknowledges, due to
the site-specific nature of SCR, detailed vendor quotes are difficult
to obtain because they cannot be done in an ``off-the-shelf'' fashion.
CCM section 2.5.4.1, page 2-27. Sargent & Lundy, however, has used
example vendor quotes for major pieces of equipment, including ammonia
handling system, unity auxiliary transformers, catalyst modules, and
sootblowers and sonic horns, and adjusted the quotes as necessary to
account for the site-specific factors such as Laramie River Stations'
boiler size, flue gas rates, flue gas temperatures, and inlet and
outlet NOX concentrations. S&L Evaluation section 4.4.1;
Attachment A2. Sargent & Lundy also provided process equipment cost
estimates for manufactured equipment in Attachment E of its Evaluation.
Sargent & Lundy estimated material and commodity costs by
multiplying the quantity of the material needed to install the system
based on the conceptual design by the unit cost for the commodity,
which was estimated using Sargent & Lundy in-house data, vendor
catalogs, and industry publications. Id. section 4.4.2. The basis for
the estimates of materials is set forth in detail in the Sargent &
Lundy Evaluation. Id. section 4.4.2.1. Labor costs were estimated based
on man-hour estimates from industry publications, union craft rates for
southeastern Wyoming, and a local labor productivity factor. Id. See
also id. at Attachment F (Example Industry Publications--Commodity
Costs and Man-Hour Estimates). Where the conceptual design provided
insufficient detail on which to generate an estimated cost, Sargent &
Lundy used allowances based on the typical scope of similar projects.
Id. section 4.4.3.
Sargent & Lundy considered both fixed and variable operating and
maintenance costs. S&L Evaluation section 4.5. Variable costs for SCR
include costs of anhydrous ammonia and catalyst replacement costs,
while fixed costs include property taxes and insurance. Id. section 4.5
and Table 5. Sargent & Lundy's analysis did not use the maintenance
materials and labor cost in the CCM of 1.5% of Total Capital Investment
because it results in significantly higher than expected maintenance
costs than reported by industry. Rather, Sargent & Lundy used a lower
maintenance materials and labor cost of 0.25% of Total Capital
Investment, which results in a conservative estimate of operating and
maintenance costs. Id. section 6.1.2.
Indirect capital costs were estimated based on total direct capital
costs using the factors set forth in EPA's CCM. S&L Evaluation section
4.4.5. For large projects like SCR, with project durations of between
1.5 years and four years, Sargent & Lundy typically would account for
escalation, reflecting the increases in equipment, material, and labor
costs that occur during the duration of the project. Id. section
4.4.6.1. Sargent & Lundy has taken a
[[Page 5175]]
conservative approach in its estimate, however, and has calculated
estimates in constant 2013 dollars without including escalation, which
is consistent with the constant dollar approach discussed in the CCM.
Id.; CCM section 4.2, page 2-43.
Response: As noted on page 21 of Exhibit 14 of Basin Electric's
comments: ``. . . Cost estimates prepared for Laramie River Station are
based on equipment costs and budgetary quotes available from similar
projects and Sargent & Lundy's experience with the design and
installation of retrofit SNCR and SCR control systems. The Laramie
River Station cost estimates are conceptual in nature; thus, Sargent
and Lundy did not procure equipment quotes specifically for the Laramie
River Station control systems. Rather, equipment costs for the Laramie
River Station projects are based on conceptual designs developed for
the control systems, preliminary equipment sizing developed for the
major pieces of equipment, and recent pricing for similar equipment . .
.''
The approach used by Sargent & Lundy is essentially how the cost
algorithms for IPM were developed, upon which EPA relied. Both are
empirically-based estimates that, as demonstrated in our response to
other comments, use many of the same inputs. However, Sargent & Lundy
developed a very detailed cost estimate that includes many line items
that would otherwise be included in the Project Contingency or other
areas, such as General Facilities, and thereby double-counted these
costs.
EPA has addressed comments relative to capital cost estimates in
our other responses. EPA has reviewed the assumed variable operating
costs and has commented on them in other comments. Regarding fixed
operating costs, the IPM algorithm represents information from actual
facilities, and is therefore used in EPA's analysis. As far as indirect
capital costs, EPA agrees that escalation should not be included
because the CCM requires use of the overnight method.
Comment: When site-specific conditions are taken into
consideration, the costs of installing SCR at Laramie River Station
would total nearly $747 million, with annual costs of $86,074,000. The
per unit breakdown of capital costs are set forth in Table 5 and Table
3 of the Sargent & Lundy Evaluation. Direct costs include: Equipment,
material, labor, spare parts, special tools, consumables, and freight.
Total project costs include equipment costs for the SCR, ammonia
handling system, and balance-of-plant systems including the ID fan,
auxiliary power system, electrical system, and dry sorbent injection
control systems on Laramie River Units 1 and 2. See S&L Evaluation
section 4. Indirect costs include: General facilities, engineering and
home office fees, contingencies, preproduction costs, and initial
catalyst fills. See Cost Manual section 2.5.2, pages 2-41 through 2-47;
S&L Evaluation section 4.4.5.
In all cases, Sargent & Lundy used methodology that results in a
conservative estimate of total costs taking into account the unique,
site-specific factors discussed above. The Sargent & Lundy Evaluation
explains the effect of these factors on the cost estimate, consistent
with the BART Guidelines and the CCM. S&L Evaluation section 5.2.1; CCM
section 4.2, page 2-21. In addition, as acknowledged by EPA's own
consultant, SCR capital costs have risen significantly over the past
decade. S&L Evaluation section 5.2.1, citing Cichanowicz, Edward J.,
``Current Capital Cost and Cost-Effectiveness of Power Plant Emissions
Control Technologies,'' (January 2010).
Response: EPA disagrees with commenter and has identified numerous
deficiencies in the cost estimate developed by Sargent & Lundy for the
Laramie River Station that are discussed in previous responses to
comments. Furthermore, the IPM cost algorithm used had already been
adjusted to address escalation to 2009 dollars and, per the memo by
EPA's contractor for this action, the Chemical Engineering Plant Cost
Index (CEPCI) \224\ was used to escalate costs after that period. Per
the memo for the IPM algorithm: ``The data sets were escalated to
update the MOG information to 2009 and all of the data was cross
referenced with current 2009 projects. The MOG and S&L cost data were
updated to reflect the changes in equipment and labor rates. The CEPCI
index for power plants was used to escalate the costs. The Handy-
Whitman index was also used to escalate the project costs to account
for regional effects; the results were compared with the CEPCI index
and were within 2% for total project costs.'' \225\
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\224\ The CEPCI is an industry index that allows for adjustment
of plant construction costs from one period to another.
\225\ Sargent & Lundy, ``IPM Model--Revisions to Cost and
Performance for APC Technologies SCR Cost Development Methodology
FINAL'', August 2010, Project 12301-007, Perrin Quarles Associates,
Inc. p 1.
---------------------------------------------------------------------------
Comment: The Sargent & Lundy Evaluation considers site-specific
data, including operating parameters for the Laramie River Station
units and design parameters for SNCR that were developed based on input
from Basin Electric and on Sargent & Lundy's extensive experience. S&L
Evaluation section 4.1, Table 1. See also id. at Attachment A1. Prior
to undertaking the cost estimate, Sargent & Lundy developed a
conceptual design taking into consideration site-specific design and
operating parameters. S&L Evaluation section 4.2.1. The Evaluation
highlights each of these project-specific considerations, which
include, among other items: (1) Considerations Related to Use of Urea
as the Reagent. The SNCR estimate is based on use of urea as a reagent,
which would be delivered by truck and unloaded into fiberglass
reinforced plastic storage tanks. The tanks would be cross tied and
solution would be transferred using stainless steel piping. Centrifugal
pumps would be needed to pump solution to metering modules and variable
frequency drives would be used to maintain constant pressure. Finally,
distribution modules would be needed to provide diluted urea solution
and atomizing air to individual injectors. The design, quantity, type
and placement of injectors are critical to SNCR performance. (2)
Furnace Modifications. Penetrations in the boiler water wall would be
required at injector locations; and to support injector penetrations,
water wall tubes would need to be removed and replaced with tubes
curved around the location. Also, reinforcement may be necessary to
support the injectors. (3) Process and Freeze Protection Tracing
System. A freeze protection system would be necessary for outdoor
piping and instruments. The system would be designed to accommodate
both normal plant operations and extended shutdowns during cold
weather. S&L Evaluation section 4.2.2.
The equipment costs were estimated based on SNCR original equipment
manufacturers for control systems on similar coal-fired boilers in
light of the conceptual design of the control technology. Equipment
costs were developed for SNCR metering skids and injectors,
compressors, reagent storage tanks, and related ancillary equipment.
Id. section 4.4.1. Consistent with the SCR cost estimate, material and
commodity quantities for structural, mechanical and electrical items
were developed for each subsystem included as part of the SNCR system
and provided as inputs to the cost calculation. Id. section 4.4.2.1.
Material and commodity pricing was based on in-house data, vendor
catalogs, and industry publications. Id. Where the
[[Page 5176]]
conceptual design provided inadequate detail on which to base costs,
allowances were used. Id. section 4.4.3. Similar to the SCR cost
estimate, labor costs were based on local labor rates, with an estimate
of man-hours required for installation of each line item in the SNCR
estimate. Id. section 4.4.4.
Indirect capital costs were based on the CCM, using default factors
set forth in Section 4.2, Chapter 1, Table 1.4. Id. section 4.4.5. The
estimate includes variable and fixed operating and maintenance costs,
including costs for urea. Id. section 4.5. Sargent & Lundy did not
include either escalation or AFUDC in its cost estimate because the
installation of SNCR systems are less capital and time intensive and
can be done in a shorter period of time than SCR systems. S&L
Evaluation section 4.4.6.3.
Based on methodology consistent with the CCM, total site-specific
costs for installation of SNCR at Laramie River Station are
approximately $50.5 million, with annual costs of $19.75 million. The
breakdown of total costs per unit can be found at Table 2 of the
Sargent & Lundy Evaluation.
Response: Based upon information provided by Basin Electric in
their comments, EPA has accepted Basin Electric's estimated capital
cost for SNCR and the estimated chemical utilization.
Comment: The Sargent & Lundy Evaluation supports Wyoming's BART
determination. The average effectiveness of both SNCR and SCR are high,
and the incremental cost of SCR compared to SNCR is even higher.
Sargent & Lundy calculated the cost effectiveness of SNCR and SCR
technologies based on emission rates resulting from Laramie Rivers'
installation of LNB and OFA, consistent with the BART Guideline's
directive to use baseline emission rates that ``represent a realistic
depiction of anticipated annual emissions for the source.'' 70 FR
39167. For comparison purposes, Sargent & Lundy also performed a
sensitivity analysis showing the values generated by using the 2001
through 2003 emission rates, which EPA's relied upon in making the BART
determination in its proposed FIP. S&L Evaluation section 6.1.3, Tables
11-12. The cost effectiveness of SCR still remains between $5,955 and
$6,298 costs per ton of NOX removed and incremental cost
effectiveness from SNCR is above $9,000 per ton of NOX
removed. Id. Table 12. These cost effectiveness values remain
prohibitive, and reinforce Wyoming's determination that OFA plus LNB
constitutes BART at Laramie River and EPA's 2012 rejection of SCR as
not cost effective.
The Sargent & Lundy Evaluation further supports Wyoming's BART
determination for Laramie River Station by providing a more precise
cost estimate for both SCR and SNCR. At significant expense, Basin
Electric arranged for an evaluation of the costs of compliance with SCR
and SNCR at a level of detail that far exceeds what the CCM requires,
but represents the gold standard for estimating the costs of compliance
for a control technology. This evaluation demonstrates that the costs
to install SCR at Laramie River would reach $750 million, far above
what EPA estimates in the proposed SIP disapproval and FIP. In sum, the
Sargent & Lundy Evaluation supports Wyoming's BART determination, and
its decision not to require SCR, with a detailed consideration of the
costs of compliance for Laramie River. Moreover, the Evaluation
highlights the fundamental inadequacies in EPA's own cost estimates, on
which EPA bases both its decision to disapprove the SIP and the BART
determinations in its FIP.
Response: EPA disagrees with commenter and has identified numerous
deficiencies in the cost estimate developed by Sargent & Lundy for the
Laramie River Station that are discussed in previous responses to
comments. EPA calculated emission reductions from emission rates
indicative of pre-BART levels in 2001-2003, prior to addition of
combustion controls for BART. The estimated reduction of NOX
by SNCR and SCR used baseline levels that were based upon actual
emission rates achieved after the addition of those combustion
controls.
Comment: The EPA's expert, Andover, used aerial photographs to
assess the structural and mechanical changes necessary for installation
of the SCR. As witness Ken Snell demonstrated at the July 26, 2013,
public hearing, however, an aerial photograph is wholly inadequate to
assess site-specific conditions that affect SCR costs. Those relevant
site-specific conditions include, among others, the following: (1) Site
elevation--Laramie River is situated at 4,750 feet above mean sea level
(MSL), a fact which affects the flue gas volume which require a larger
SCR reactor, duct work and structural support; (2) Regional labor
productivity factor--necessary to account for local workforce
characteristics, labor availability, project location, project
complexity, local climate and working conditions; (3) Location of
conveyor rooms--aerial photo cannot reveal conveyor rooms located in
boiler buildings; (4) Location of FD Fan buildings--aerial photo cannot
reveal the location of the existing FD fan buildings; (5) Space
constraints--aerial photo cannot determine the space constraints
between the FD fan buildings and existing ESPs; (6) Ammonia handling--
aerial photo cannot provide information about where the ammonia
handling system required for an SCR could be located, or where pipe
routing could be placed; (7) Ductwork routing--aerial photo does not
provide information regarding ductwork routing and SCR tie-ins to the
existing economizers and air heaters; and (8) Subsystems ignored--
aerial photo does not provide any information regarding plant
subsystems such as ID fan capacity, equipment reinforcement, auxiliary
power systems, electrical system capacity, or other plant subsystems.
Failure to take into consideration the site-specific, plant-
specific characteristics for installation of SCR systems necessarily
leads to a significant underestimation of the costs to install such
control technology. EPA's expert Andover, using generalized data and an
aerial photograph, estimated the total capital investment for
installation of an SCR at $330,000,000. However, when actual site
conditions are considered--i.e. site elevation, regional productivity
factors, site congestion, balance-of-plant subsystem upgrades and other
indirect costs--expert Ken Snell estimated the total capital investment
at $746,906,000. Failure of EPA's expert to take into consideration the
Laramie River Station's specific characteristics and plant
configuration omits approximately $460,000,000 in very real costs. To
turn a blind eye to site-specific characteristics that have a major
impact on costs of installation skews the EPA's cost analysis by more
than 100 percent. Basing the Laramie River Station BART determination
on EPA's cost estimates would be arbitrary and capricious.
EPA proposes to reject Wyoming's SIP despite a finding that
``Wyoming considered all five steps above in its BART determinations''
because of alleged ``flaws and deficiencies'' in the cost assumptions
and methodology, including Wyoming's alleged failure to ``follow the
methods set forth in the EPA Control Cost Manual.'' 78 FR 34748-34749.
To address these alleged deficiencies, EPA hired its own consultant,
Andover Technology Partners (``Andover''), to perform an independent
cost analysis of installing SNCR and SCR at the Laramie River Station.
Andover, Review of Estimated Compliance Costs for Wyoming Electricity
Generating Units (EGUs)
[[Page 5177]]
(Oct. 23, 2012), EPA-R08-OAR-2012-0081 (``Andover Report''); Andover,
Review of Estimated Compliance Costs for Wyoming Electricity Generating
Units (EGUs)--revision of previous memo (Feb. 7, 2013), EPA-R08-OAR-
2012-0086 (``Andover Update''). Ironically, it is the cost methodology
relied upon in the Andover Report that deviates from the BART
Guidelines and the CCM, thereby making Andover's analysis inconsistent
with EPA's claim that cost estimates should not deviate from the CCM.
As a result, EPA's cost estimates are less accurate than the Wyoming
cost estimates and the Sargent & Lundy Evaluation and do not form a
legally supportable basis on which to base either a SIP disapproval or
the promulgation of a FIP.
Sargent & Lundy, at Basin Electric's request, has provided a
critique of the Andover Report that highlights the numerous technical
irregularities in the cost estimate relied upon by EPA for the proposed
disapproval of the Wyoming SIP and the FIP. Sargent & Lundy Laramie
River Station Andover Report Comparison (August 26, 2013), Exhibit 16
(``S&L Critique'') to commenter 0148. The Sargent & Lundy Critique
demonstrates that EPA's reliance on the Andover Report is not in
accordance with section 169A of the CAA and the BART Guidelines for
three reasons: (1) Andover relied primarily on the IPM for cost
methodology, which is not consistent with the BART Guidelines or the
CCM methodology and never was intended to be used to develop a site-
specific cost estimate. (See section 2.3, EPA Use of the IPM Cost
Models.); (2) Andover failed to take into account site-specific
conditions and resulting balance of plant systems required for SCR and
SNCR and therefore did not comply with the directive in the BART
Guidelines that cost estimates ``take into account any site-specific
design or other conditions . . .'' 70 FR 39166.; (3) Andover ignored
NOX reductions achieved to date by existing control
equipment, thereby artificially increasing the cost effectiveness of
SCR.
If EPA is basing its SIP disapproval on failure to adhere to the
methodology set forth in the CCM, EPA's reliance on the cost estimation
in the Andover Report is wholly inappropriate and imposes an arbitrary
double standard. Not only does the Andover Report rely on methodology
that deviates from the CCM, but EPA's approach is inconsistent with the
requirements of the BART Guidelines because it does not adhere to the
three-step approach for cost estimation set forth in the Guidelines and
fails to appropriately account for ``site-specific design or other
conditions'' that ``affect the cost of a particular BART technology
option.'' 70 FR 39166. Reliance on the Andover Report for disapproval
of the Wyoming SIP or imposition of a FIP would constitute arbitrary
and capricious decision making and would run contrary to the very
provisions of law on which EPA proposes to base its decision.
Response: EPA disagrees with commenter and has identified numerous
deficiencies in the cost estimate developed by Sargent & Lundy for the
Laramie River Station that are discussed in previous responses to
comments. EPA has also noted in other responses to comments that,
except for elevation, each of the site-specific issues raised by
commenter has been addressed, or commenter has not provided adequate
information to support their assertion that there are unique costs that
are not accounted for in EPA's cost estimate. We disagree with the
characterization of the cost development methodology contained in IPM
as inconsistent with BART guidelines. As noted in the documentation for
IPM's cost development methodology for SCR, the cost estimate
methodology is based upon two databases of actual SCR projects.\226\
These databases include 2004 and 2006 industry cost estimates prepared
for the Midwestern Ozone Group, and a proprietary in-house database
maintained by engineering firm Sargent & Lundy. The Midwestern Ozone
Group information was cross-referenced with actual 2009 projects, and
as explained elsewhere in this document, escalated accordingly. Sargent
& Lundy then used the information in these databases to develop the
equations described in the cost component taking into account the pre-
control NOX emission level, degree of reduction, coal type,
facility size, and numerous other unit-specific factors. While a costly
engineering evaluation that included site visits in addition to our use
of satellite imagery might be useful, we disagree that our approach is
not sufficiently site specific to satisfy BART guidelines. As noted by
EPA in previous responses, EPA's use of satellite imagery enabled us to
evaluate each of the major site-specific issues.
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\226\ https://www.epa.gov/airmarkets/progsregs/epa-ipm/docs/v410/Appendix52A.pdf.
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Comment: EPA argues that ``[w]hen considering the cost
effectiveness and visibility improvement of new LNBs plus OFA and SCR,
it is within the range of what EPA has found reasonable for BART in
other SIP and FIP actions.'' 78 FR 34776. EPA's cost effectiveness and
visibility improvement numbers for Laramie River Station Units 1-3 are
within the range of what EPA has found not to be reasonable for BART.
The case for rejecting SCR becomes even more compelling when EPA's
numbers are corrected to comply with the BART Guidelines, CCM, and EPA
guidance, and to reflect site specific conditions. With these comments,
Basin Electric is submitting updated and more accurate reports with
cost estimates and visibility modeling results based on inputs that are
more correct and consistent with EPA's BART Guidelines. Average and
incremental cost effectiveness values for SCR at Laramie River Station
in these reports are far higher than assumed by EPA, and visibility
improvement associated with SCR is far lower than EPA assumed. For EPA
to disapprove the State's BART determination for Laramie River Station
and proceed with its FIP in light of this new information would be
egregiously inconsistent with BART actions it has taken for other
sources.
The following discussion explains that even with EPA's cost and
visibility values for Laramie River Station, its proposed action at
Laramie River Station is inconsistent with actions elsewhere and EPA
should withdraw its proposed disapproval.
The comparison to Gerald Gentleman Station (GGS) Units 1-2 is
striking. SCR was rejected at GGS despite substantially lower costs and
very similar visibility improvement. GGS is a valid point of comparison
despite the fact that Nebraska adopted the Transport Rule as a BART
alternative. 77 FR 40159. EPA did not make a final determination as to
whether to select SCR as BART for GGS because Nebraska became subject
to the Transport Rule and relied on that as a BART alternative. Id.
However, EPA's proposed rule discusses the costs and benefits of SCR.
77 FR 12770, 12779 (March 2, 2012). In its proposed rule, EPA agrees
with Nebraska's decision to reject SCR at an average cost effectiveness
of $2,297/ton and an incremental cost effectiveness of $5,445/ton (both
as calculated by Nebraska). The projections of visibility improvement
were the same in the proposal and the final rule, i.e. 0.62 delta
deciview for each of GGS Units 1 and 2. The proposed rule states that
``EPA agrees that the State's NOX BART determination for GGS
is reasonable.'' 77 FR 12779. EPA never retracted that conclusion.
The difference between EPA's pending proposals for Wyodak Unit 1
and Laramie River Station Units 1-3 are equally striking. The average
and incremental cost effectiveness is virtually the same for these
units. So are
[[Page 5178]]
the baseline and incremental visibility improvement figures. Yet EPA
proposes to require LNB, OFA and SNCR at Wyodak Unit 1, as opposed to
LNB, OFA and SCR at each Laramie River Station unit. 78 FR 34785. EPA
bases these differing outcomes on the fact that SCR at Wyodak Unit 1
would achieve a cumulative visibility improvement of 1.16 deciviews,
whereas SCR at Laramie River Station Units 1-3 would reportedly achieve
cumulative visibility improvements of 2.12, 1.97, and 2.29. Id.
Cumulative visibility improvement at multiple Class I areas is not a
valid criterion for use in BART determinations. Disregarding the
invalid cumulative criterion, EPA inconsistently eliminated SCR as BART
at Wyodak based on cost and visibility values very similar to EPA's
cost and visibility values for Laramie River Station.
Also noteworthy is EPA's decision to reject SCR as BART at Healy
Unit 1 because of its $5,300/ton cost effectiveness, 0.786 deciview
visibility improvement from the LNB/OFA baseline, and 0.17 deciview
incremental improvement compared to SNCR. EPA recalculated the costs
after publishing its proposed rule to account for various potential
useful life scenarios. The $5,300/ton figure shown here is for a 30
year life. For a 20 year useful life, SCR would cost $5,900/ton. EPA
concluded that these costs are ``not justified'' given the visibility
improvement (which was not recalculated after proposal).
A comparison of the costs and visibility impacts of installing and
operating SCR at Laramie River Station Units 1-3 to the costs and
visibility impacts of SCR at the facilities listed above quickly shows
that SCR must be rejected as BART. EPA has made no attempt to explain
why it proposes to disapprove the State's BART for Laramie River
Station and proposes SCR instead, when it has eliminated SCR at other
facilities based on similar information. To the extent the information
at the other facilities is a little different than at Laramie River,
EPA has not and cannot show that the difference is significant or a
reason to treat the facilities differently.
Response: We disagree with the commenter's assertion that our
proposed action for Laramie River Station, as it relates to the
consideration of SCR as BART, was inconsistent with our proposed action
for other BART sources in Wyoming or with EPA actions in other States.
Regarding NOX BART for Gerald Gentlemen Station in
Nebraska, we note that our proposed approval of the State's
NOX BART determination, as described by the commenter, does
not reflect final agency action. In our final rulemaking for Nebraska,
where the State is subject to the Transport Rule and FIP for
NOX, we provided the following:
Given the emission reductions provided by the NOX
emission limits associated with Nebraska's NOX BART
determination of LNB and OFA for GGS Units 1 and 2, which strengthen
the Nebraska SIP, in conjunction with the existing Transport Rule
FIP which already applies to Nebraska and has been determined to
provide greater reasonable progress than BART, in today's action,
EPA is finalizing its proposed approval of Nebraska's SIP as
satisfying the requirements of the Regional Haze Rule with respect
to BART for NOX, and therefore do not inquire further
here as to whether the cost effectiveness of SCR is low enough and
the associated deciview improvement significant enough to reasonably
determine that SCR is BART for GGS Units 1 and 2.\227\
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\227\ 77 FR 40159 (emphasis added).
Therefore, because the Transport Rule removed the need for EPA to
consider SCR for Gerald Gentlemen Station any further, there is no
factual basis to determine whether our consideration of SCR in Wyoming
differs from that in Nebraska. In simpler terms, the commenter has
erred by drawing a comparison with a BART determination that was never
finalized.
We also disagree that our proposed NOX BART
determinations for Laramie River Station were inconsistent with that
for Healy Unit 1 in Alaska. There, the cost effectiveness of SCR, using
a 20 year lifetime comparable to that used for Laramie River Station,
was found to be $5,900/ton.\228\ This cost effectiveness is greater
than that for any of the Wyoming units for which EPA proposed SCR as
BART, or for which EPA is finalizing SCR as BART today. The cost
effectiveness of SCR (with combustion controls) for Laramie River
Station units estimated by EPA in our proposed rule ranged from $3,589/
ton to $3,903/ton \229\--at least 34% less than at Healy Unit 1. While
we have revised these costs effectiveness estimates for today's rule,
they remain well below the $5,900/ton cost effectiveness that EPA
calculated for Healy Unit 1.
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\228\ 78 FR 10548.
\229\ 78 FR 34775-34776.
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Finally, while the costs and visibility improvement (at one Class I
area) for the Laramie River units and Wyodak described in our proposed
rule may have been similar, we disagree that the cumulative visibility
benefit was not a valid criterion for use in BART determinations. Refer
to the modeling section above where we address our consideration of
cumulative visibility benefits.
We have addressed the updated cost estimates and visibility
modeling submitted by Basin Electric during the public comment period
in other response to comments.
Comment: SCR should be rejected for Laramie River Station Units 1-3
because of its high cost per deciview of visibility improvement. EPA
did not report the $/deciview for Laramie River Station, but dividing
the annualized costs by the visibility improvement (from the pre-LNB/
OFA baseline) reveals that SCR would cost between $23.0 million and
$27.8 million per deciview of improvement in the Class I area with the
greatest visibility improvement. These figures are very similar to the
$/deciview numbers seen at Martin Drake, Colstrip, Corette, and GGS,
and substantially higher than the $10.8 million and $20 million figures
reported for Lakeland Electric and JEA Northside. The Laramie River
figures are also well above the $14 million to $18 million per deciview
range that has frequently been seen as cost effective. EPA has not
considered or justified SCR at Laramie River in light of its high cost
per deciview.
Not only has EPA proposed to mandate SCR for Laramie River at $/
deciview levels where SCR has previously been rejected, EPA has
frequently refused to apply the $/deciview metric in accordance with
the BART Guidelines. The Guidelines expressly allow states to evaluate
control technologies based on ``cost-effectiveness measures (such as $/
deciview),'' 70 FR 39170, but EPA has generally opposed reliance on
such a standard by the states. While acknowledging that the dollar per
deciview is ``an additional cost effectiveness metric that can be
employed along with $/ton for use in a BART evaluation,'' EPA has not
used $/deciview because it is ``unnecessary,'' it ``complicates the
BART analysis,'' and it is ``difficult to judge.'' 77 FR 57871. In
other rulemakings, EPA has stated that ``[w]e do not generally
recommend the use of this metric as it can be complicated to use and
the results can be difficult to assess.'' 77 FR 76871, 76873 (Dec. 31,
2012). EPA also has objected to the $/deciview metric because it claims
that metric is based on the impacts of a single day. 77 FR 57871.
EPA's reasons for refusing to consider the $/deciview metric are
frivolous. Even if the $/deciview metric is complicated or difficult to
use, that does not distinguish it from any other aspect of the BART
determination process. EPA's concern that the $/deciview metric is
based on a single day holds no
[[Page 5179]]
water. EPA sometimes bases the visibility improvement (delta deciview)
of potential control technologies on the ``maximum 98th percentile
impact,'' meaning the 98th percentile day with the highest deciview
improvement during the relevant period, and proposes to do so in its
analysis of Laramie River. 78 FR 34775. Indeed, it is that day's
deciview improvement which is used to calculate $/deciview. The $/
deciview metric has the virtue of directly comparing cost to visibility
improvement. It would constrain EPA's current use of a nebulous sliding
scale where the agency gives itself the latitude to point to any one of
several variables as justification for overriding the State's choice of
BART or for making its own.
Response: We disagree that our reasons for not considering the $/
deciview metric are frivolous. We maintain that, for the reasons
discussed in other regional haze actions, as cited by the commenter,
the $/deciview metric is problematic and does not offer any better
basis for making BART determinations than those used by EPA here--cost
effectiveness, incremental cost effectiveness, and visibility
improvement. Moreover, the BART Guidelines do not require EPA or the
states to conduct a $/deciview analysis when evaluating the visibility
improvement factor. Instead, the BART Guidelines allow flexibility in
this area, stating that: ``You have flexibility to assess visibility
improvements due to BART controls by one or more methods. You may
consider the frequency, magnitude, and duration components of
impairment.'' 70 FR 39170. While the BART Guidelines suggest cost per
deciview as a possible parameter for consideration, its use is entirely
discretionary. There are numerous examples of BART analyses conducted
by states and EPA that have not calculated this metric.
Comment: The Laramie River Station began commercial operation in
July, 1980, with a permitted limit for NOX emissions of 0.71
lb/MMBtu. However, Laramie River was able to significantly outperform
its permitted limits, achieving an average emission rate that was much
lower, approximately 0.45 lb/MMBtu. In 1996 and 1997, Laramie River
replaced burner nozzles on all three units and again reduced its
NOX emission rates, to an average of about 0.27 lb/MMBtu.
Now, pursuant to Wyoming's BART permit, Laramie River is required to
further reduce its NOX emissions to a limit of 0.21 lb/MMBtu
and 14,474 tons/year in 2014, and reduce emissions even further by the
end of 2017, to 12,773 tons/year (equivalent to 0.158 lb/MMBtu). By
2017, the Wyoming regional haze SIP will have required the station to
reduce its NOX emission rate by 65% from the NOX
rate emitted when the units were originally started up. This
demonstrates that the State has achieved very substantial
NOX emission reductions without undue and wasteful expense.
To put the reductions already achieved in perspective, the
combination of past reductions and future required reductions results
in total NOX reductions at Laramie River of 0.29 lb/MMBtu
(from 0.45 lb/MMBtu to 0.158 lb/MMBtu). This has been done and will be
done at a significant but reasonable cost. In contrast, EPA proposes to
require the expenditure of nearly $750 million dollars to reduce
NOX emissions further, from 0.158 1b/MMBtu to 0.05 lb/MMBtu,
a reduction of only 0.11 lb/MMBtu, less than half of what has already
been accomplished.
Response: We disagree with this comment. The RHR and BART
Guidelines instruct states to calculate the cost-effectiveness and
visibility improvement associated with the various control options
against a realistic emissions baseline. For the purposes of BART, most
states, including Wyoming, used a baseline period of 2000-2004, which
corresponds to the five-year period that followed the promulgation of
the RHR. Setting a baseline that predates the promulgation of the RHR,
as the commenter suggests, would be inappropriate because it would
allow emission reductions that were achieved as the result of
compliance with other CAA programs to be attributed instead to BART.
Thus, any reductions achieved at Laramie River between 1980 and 1997
cannot be credited to the source owner, but must be incorporated into
the baseline, as both the State and EPA properly did in this case. In
regards to reductions achieved at Laramie River that have been or will
be achieved due to compliance with the State's BART determination,
these reductions will also occur under EPA's FIP. Consequently, a more
accurate way of comparing the State's regional haze SIP to EPA's FIP is
to subtract the ultimate emission rate achieved by each plan from the
baseline. Using the commenter's emission rates, the State's regional
haze SIP would reduce emissions at Laramie River by 0.112 lb/MMbtu from
the baseline, while EPA's FIP will reduce emissions by 0.22 lb/MMbtu.
For a more detailed discussion of baseline emissions and the flaws in
the commenters' logic, see our response to similar comments on the
consideration of existing controls in use at a source.
Comment: The costs of installation of the SCRs at Laramie River
Station impose an economic impact that is unjustified by the facts of
this case. The regulation of regional haze is focused on improving
visibility, not public health. Yet, the improvement in visibility that
EPA suggests will be created by installation of SCRs, as opposed to the
Wyoming SIP's LNBs/OFA, does not carry with it a significant
improvement in visibility. By EPA's own calculations, installation of
SCRs will result in only a 0.79 deciview visibility improvement at the
most impacted Class I area, Badlands National Park, and those
calculations substantially overstate the visibility improvement that
would actually be achieved. By its very definition, this small
incremental improvement in visibility is not even perceptible by the
human eye.
Response: We disagree with this comment. As stated in section
IV.C.5 above, even though the visibility improvement from an individual
source may not be perceptible, it should still be considered in setting
BART because the contribution to haze may be significant relative to
other source contributions in the Class I area. Thus, we disagree that
the degree of improvement should be contingent upon perceptibility.
Failing to consider less-than-perceptible contributions to visibility
impairment would ignore the CAA's intent to have BART requirements
apply to sources that contribute to, as well as cause, such
impairment.\230\
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\230\ The preamble to the BART Guidelines state, ``[e]ven though
the visibility improvement from an individual source may not be
perceptible, it should still be considered in setting BART because
the contribution to haze may be significant relative to other source
contributions in the Class I area. Thus, we disagree that the degree
of improvement should be contingent upon perceptibility. Failing to
consider less-than-perceptible contributions to visibility
impairment would ignore the CAA's intent to have BART requirements
apply to sources that contribute to, as well as cause, such
impairment'' (70 FR 39104, 39129, July 6, 2005).
---------------------------------------------------------------------------
Comment: EPA asserts that Wyoming's alleged ``deviations'' from the
BART Guidelines and CCM form adequate grounds for rejection of its
SIP--yet the BART determinations included in EPA's proposed FIP eschew
the very standards to which it holds the State. EPA's estimate of the
``cost of compliance'' for installation of SCR and SNCR at Laramie
River Station is grounded in an outside consultant's report that
expressly dismisses the recommendations of EPA's own CCM in favor of a
methodology that is inconsistent with the directives of the BART
Guidelines and fails to account
[[Page 5180]]
for critical site-specific factors that affect the cost of these
technologies at Laramie River. The resulting cost estimates are not
representative of the costs that Basin Electric would incur for the
installation of SCR and SNCR and do not form a legally supportable
basis on which to promulgate a FIP. To finalize a FIP based on the cost
effectiveness estimates in the Andover Report would constitute
arbitrary and capricious decision making and would run contrary to the
same provisions of law on which EPA bases its disapproval of Wyoming's
SIP.
The Andover Report uses a high-level model that was never intended
to be used to estimate site-specific costs. But neither Andover nor EPA
offers any explanation of why reliance on the IPM model is more
appropriate than either the CCM recommendations or a site-specific
scoping level study such as the Sargent & Lundy Evaluation. Indeed,
EPA's preamble notes that the cost estimate relied primarily on the IPM
model, but then simply parrots the conclusions of the Andover Report
without further analysis or discussion. Although EPA has the discretion
to rely on a model of its choice, EPA's reliance on the IPM model to
estimate costs requires both an explanation of the assumptions made and
a defense of this particular methodology--particularly because EPA has
proposed disapproval of Wyoming's SIP for failure to adhere strictly to
the CCM methodology. See Appalachian Power, 249 F.3d at 1053. EPA has
failed to ``make plain its course of inquiry, its analysis and its
reasoning'' and therefore promulgation of a FIP based on the Andover
Report would be arbitrary and capricious. Olenhouse, 42 F.3d at 1575.
EPA's BART determinations relied upon methodology that does not
comply with the BART Guidelines. Specifically, Andover did not adhere
to the three-step process in the BART Guidelines for estimating the
``costs of compliance'' because the analysis set forth in the report
did not adequately define the emission units being controlled, failed
to identify site-specific design parameters that affect cost and
performance of the controls, and used the IPM model to develop cost
estimates that are neither technically defensible nor representative of
the costs of SCR and SNCR systems at Laramie River.
First, Andover's use of the IPM model--which requires only four
inputs--is so general that it failed to adequately define the operating
parameters of Laramie River Station Units 1 through 3. Second, both the
IPM model and Andover's manipulation of the cost algorithms ignored
numerous site-specific variables that would have a substantial effect
on the costs incurred by Basin Electric. These variables include, among
other items, failure to account for the elevation of Laramie River and
the complexities of SCR at the facility. Finally, Andover used out-of-
date and inaccurate emissions from Laramie River Units 1 through 3 on
which to base its cost effectiveness analysis. These emissions
estimates did not take into consideration the reductions that result
from the installation of OFA and LNB at these units, which have reduced
the baseline NOX emissions to 0.19 lb/MMBtu. As a result of
these inadequacies, the Andover Report makes inaccurate cost estimates
that are not representative of the costs that Basin Electric would
incur for installation of either SNCR or SCR. By relying on the Andover
Report, EPA has ``complete[ly] failed to consider the criteria that
should inform'' its BART determination, and a court would accord EPA's
BART determination no deference and would determine that it is
arbitrary, capricious, an abuse of discretion and not in accordance
with the law. Nat. Resources Defense Council, 725 F.2d at 771; see also
Appalachian Power, 249 F.3d at 1052; Sierra Club v. Costle, 657 F.3d at
333.
Response: Each of the commenter's claims have been addressed above
in other responses and elsewhere in this document. In these responses
we have substantiated that the cost methodology employed by EPA,
including use of the IPM-based cost algorithms, is consistent with the
BART Guidelines and CCM. Moreover, we modified our cost estimates in
response to site-specific information provided by Basin Electric during
the comment period. Therefore, we reject the commenter's assertions
that (1) we have dismissed the recommendations of the CCM in favor of a
methodology that is inconsistent with the directives of the BART
Guidelines, and (2) failed to account for critical site-specific
factors.
We have addressed the commenter's concern regarding whether our
cost-effectiveness analysis reflects the relatively lower emissions
achieved with recent combustion control updates (OFA and LNB) in
section V.A.12 above.
Comment: Wyoming concluded that SCR would lower the NOX
emission rate of Laramie River Units 1-3 to 0.07 lbs/MBtu on a 30-day
rolling average basis and used the 0.07 lbs/MMBtu controlled
NOX rate to estimate costs. 78 FR 34748; WDEQ Revised NOX
BART Impact Analysis AP-6047A (January 3, 2011) (``2011 Revised BART
Analysis'') at 3, Table 2-2, docket cite EPAR08-OAR-2012-0026-0003.
The State's administrative record supports its selection of 0.07
lb/MMbtu on a 30-day rolling average as an appropriate post-SCR
NOX emissions rate. Wyoming first presented this emissions
rate in its BART Application Analysis AP-6047. Wyoming BART Analysis at
8, Table 2. Wyoming explained its rationale in its December 31, 2009
response to comments on BART Permit AP-6047. Available at EPA-R08-OAR-
2012-0026-0058, Exh. 3.
Wyoming then provided a table comparing SCR control efficiencies at
seven similar coal fired EGUs. The NOX emission rate
selected by Wyoming is squarely within the range of control
efficiencies identified by the State's search. Of note are the
NOX emission rates for the Iatan Station (0.08 lb/MMbtu, 30-
day average), Big Cajun II Power Plant (0.07 lb/MMBtu annual average),
and OPPD--Nebraska City Station (0.07 lb/MMbtu, 30-day average). Id.
Wyoming's explanation and supporting data negate any contention that
the State violated the CAA or acted unreasonably when it chose to
evaluate SCR using a NOX control efficiency of 0.07 lb/MMbtu
on a 30-day rolling average basis.
EPA contends that whereas Wyoming assumed that adding SCR controls
at Laramie River would achieve a control effectiveness of 0.07 lb/
MMBtu, ``EPA has determined that on an annual basis SCR can achieve
emission rates of 0.05 lb/MMBtu or lower.'' 78 FR 34748. EPA provides
no explanation and cites nothing to support how it ``determined'' this
to be the case. It doesn't associate the 0.05 lb/MMBtu with any
specific facility or unit--it just makes this blanket assertion.
Nor can EPA assert that Wyoming's 0.07 lb/MMBtu assumed control
level conflicts with the CAA or the BART Guidelines. Nothing in the
Guidelines dictates what SCR can achieve, and EPA cites no provision of
the Guidelines to support its claim. In fact, EPA's blanket claim that
0.05 lb/MMBtu must always be used itself conflicts with the Guidelines,
which make clear that BART is a site-specific determination, not a
blanket finding. The notion that EPA can apply an across-the-board
value and thereby deprive the State of its ability to exercise
discretion on an individual case basis is contrary to the holding in
American Corn Growers, 291 F.3d at 7-10.
The lack of support for EPA's claim that the 0.07 lb/MMBtu is a
``flaw'' is reinforced by EPA's own acceptance of this value in BART
analyses by other States. For example, in Colorado, commenters on EPA's
proposed
[[Page 5181]]
approval of the State's regional haze SIP, including BART
determinations, argued that the State was wrong in assuming that at
Tri-State's Craig Station Units 1 and 2, SCR would achieve only a 0.07
lb/MMBtu NOX emission rate on an annual basis; however, EPA
did not disapprove Colorado's BART determinations for this reason or
find that this was an error. EPA's response to the comments stated that
it agreed that ``SCR in some cases can achieve annual NOX
emission rates as low as 0.05 lb/MMBtu'' but that the ``annual emission
rate assumed by Colorado, 0.07 lb/MMBtu, is within the range of actual
emission rates demonstrated at similar facilities in EPA's Clean Air
Markets Division (CAMD) emission database.'' 77 FR 76871, 76873.
Similarly, although commenters argued that SCR at Alaska's Healy Unit 1
could achieve a NOX emission rate of 0.035 lb/MMBtu, EPA
evaluated using a rate of 0.07 lb/MMBtu to evaluate SCR. 78 FR 10546,
10548. EPA evaluated SCR using an emission rate of 0.06 lb/MMBtu for
Nevada's Reid Gardner Generating Station. 77 FR 21896, 21903 (calling
this a ``mid-range option'').
Also, EPA accepted an even higher post-SCR NOX emission
rate of 0.10 lb/MMBtu for Jeffrey Energy Center Units 1 and 2. Kansas
SIP Approval, 76 FR 80754, 80756. This emission rate was ``within the
range of effectiveness that the State believed to be reasonable as a
retrofit control on older tangential-fired units.'' Id. EPA deferred to
Kansas, noting that ``EPA believes the State's decision to choose a
control efficiency within the middle of the range for the purpose of
estimating cost is a reasonable approach and is acceptable according to
the BART Guidelines.'' Id. If it was not error and not unreasonable or
arbitrary for Colorado and Kansas to use 0.07 or 0.10 lb/MMBtu, it
cannot be error, or unreasonable, or arbitrary, for Wyoming to use the
same or lower value.
Response: We have addressed the control effectiveness of SCR above
in section V.C.3 above. Again, we agree that it was appropriate for
Wyoming to set the 30-day rolling average emission limit for SCR
installations at 0.07 lb/MMBtu. And again, EPA's use of an actual
annual emission rate of 0.05 lb/MMBtu for cost calculation purposes is
supported by information supplied by control equipment consultants or
vendors and submitted along with comments from PacifiCorp and Basin
Electric.
We also note that the commenter has compared the 30-day allowable
rates established at certain facilities to the annual emission rate
used by EPA to calculate cost effectiveness. These values are not
directly comparable. This is because: (1) The former is on a 30-day
basis, while the latter is on an annual basis, and (2) the former is an
allowable emission limit, while the latter is an actual emission rate.
The remaining comments have been addressed elsewhere in this
document.
Comment: For the same reasons that SNCR is not a relevant basis for
disapproving Wyoming's BART for Laramie River Station, the price of
urea is likewise not relevant. The price of urea relates only to SNCR
technology, not to SCR. As noted above, SNCR is not a relevant factor
to support EPA's rejection of the State's NOX BART for
Laramie River Station because neither the State's SIP nor EPA's
proposed FIP chooses SNCR as BART. SNCR has been taken off the table by
EPA, so the attempt to base its BART disapproval on SNCR issues is
specious. EPA cannot reasonably base its disapproval on the State's
alleged failure to properly consider the cost of a technology that EPA
itself rejects.
Response: We disagree. The BART selection process requires a
comparison between all technically feasible control options, not the
evaluation of individual control technologies in isolation. While the
BART Guidelines do not specify the order in which control options must
be evaluated (e.g., beginning with the most stringent or beginning with
least stringent control), they do specify that the CAA factors must be
considered for all options: ``In the final guidelines, we have decided
that States should retain the discretion to evaluate control options in
whatever order they choose, so long as the State explains its analysis
of the CAA factors.'' 70 FR 39130. The only exceptions are ``. . . if
you find that a BART source has controls already in place which are the
most stringent controls available . . .'', or ``. . . . if a source
commits to a BART determination that consists of the most stringent
controls available . . .'' 70 FR 39165. In these situations, it is not
necessary to complete an analysis of all five BART factors. Therefore,
because neither of these criteria was met, the State was required to
perform an analysis of all five BART factors for all technically
feasible control options. And if, as EPA has established in other
responses, the analysis of one of those options, such as SNCR, was
flawed, then the State could not sensibly identify the best available
option among all of the control options considered. Therefore,
regardless of whether the State or Wyoming rejected SNCR as BART, it is
mistaken for the commenter to suggest that the analysis of SNCR was
somehow immaterial in the selection of BART.
It is particularly important that the costs of SNCR be properly
estimated in relation to the calculation of incremental cost
effectiveness. (The incremental cost of effectiveness should be
calculated in addition to the average cost effectiveness. 70 FR 39167).
The cost of SNCR affects the incremental cost effectiveness between SCR
and SNCR, as well as incremental cost effectiveness between SNCR and
combustion controls. If the cost of SNCR is incorrect, the incremental
cost effectiveness between control options will also be incorrect. This
underscores the point that, if the underlying assumptions were flawed,
the State could not have reasonably chosen between competing control
options.
We have addressed the price of urea in a separate response.
Comment: EPA is proposing that the FIP NOX BART emission
limit for Basin Electric Laramie River Unit 1, Unit 2, and Unit 3 is
0.07 lb/MMBtu (30-day rolling average). While we are generally pleased
with EPA's proposal, we note that EPA's analysis is based on only 74%
NOX control by the SCRs, and still results in each EGU
contributing 0.5 deciview to visibility impairment at Badlands National
Park.
Based on an evaluation of the rolling 30-boiler operating day
average NOX emission rates from Laramie River Units 1-3 with
emissions data available in EPA's CAMD database, a NOX limit
of 0.07 lb/MMBtu on a rolling 30-boiler operating day basis would only
require Laramie River Units 1-3 to achieve 61-70 percent NOX
removal across the SCR systems. A 0.05 lb/MMBtu NOX emission
limit applicable on a rolling 30-boiler operating day average basis
would only require 73-79 percent NOX removal across the SCR,
which is readily achievable.
Response: We have addressed the control effectiveness of SCR above
in section V.C.3 above.
Comment: Moreover, the Sargent & Lundy evaluation demonstrates,
based on a detailed scoping-level cost analysis, that SCR will cost
approximately $9,000 per ton of NOX removed, further
demonstrating the arbitrariness of EPA's proposed disapproval of the
State's NOX BART determination for Laramie River Station.
Sargent & Lundy Evaluation, Table 7.
Response: We disagree that SCR will cost $9,000/ton as indicated by
the commenter. We have incorporated certain costs claimed by Sargent &
Lundy in their evaluation, but not others. We have addressed the
Sargent
[[Page 5182]]
& Lundy cost analysis, including our rationale for not accepting
certain costs, in detail in other responses. Our revised cost analysis
of SCR plus combustion controls, indicates that the cost effectiveness
for the three units is between $4,375/ton and $4,461/ton.
Comment: EPA should have used 30-day average emission limits in the
cost effectiveness analysis, rather than expected/actual emission
rates, to be consistent with how EPA and states have done other BART
cost effectiveness calculations.
Response: We disagree. As we have stated in other responses, our
use of the anticipated actual annual emission rate is consistent with
the BART Guidelines. As we previously noted, cost effectiveness is more
appropriately based on the reduction in annual emissions, not the
change in allowable emissions.
Comment: We received a comment that EPA's consultant did not take
into account site-specific data for Laramie River Station.
Response: We have addressed this issue in a separate response. As
noted there, we have incorporated many of the costs suggested by Basin
Electric's consultant, Sargent and Lundy, in our revised costs
supporting this final action.
Comment: Wyoming has underestimated the cost of SNCR. Wyoming
estimated LNB+OFA+SNCR would cost $2,056-$2,109/ton. EPA calculated the
incremental costs of SCR versus LNB+OFA+SNCR, its preferred control
option, and estimated incremental costs of $7,054-$7,242/ton. We are
concerned that Wyoming underestimated the cost of SNCR, which biases
its emphasis on incremental costs against SCR. We calculated the costs
of SNCR using the CCM (with the reagent correction used by EPA for
Montana), and heat inputs and emission estimates from CAMD data for
2001-2003. Based upon application of the CCM, we estimate SNCR cost-
effectiveness at $2,358-$2,536/ton, which is $300-$400/ton higher than
Wyoming's estimates.
Response: We agree that Wyoming has underestimated the cost of SNCR
for the Laramie River Station units. In order to address deficiencies
in Wyoming's SNCR cost estimates for the Laramie River Station units
identified by commenters, such as the control effectiveness of SNCR, we
have conducted a revised cost analysis.
Comment: Wyoming has underestimated the ability of SCR to reduce
emissions. In estimating the annual cost-effectiveness of the
LNB+OFA+SCR option, Wyoming assumed 0.07 lb/MMBtu, which represents 74%
control efficiency on an annual average basis, as opposed to the
generally-accepted 90%. Wyoming has not provided any documentation or
justification to support the higher emission rates used in its
analyses. In other recent BART actions, EPA has determined that SCR can
achieve 0.05 lb/MMBtu on an annual basis. Such an underestimate at
Laramie River Station biases the cost-benefit analysis against SCR and
is inconsistent with other EPA analyses.
Response: The commenter has incorrectly assumed that a 90% control
efficiency can be achieved in all SCR applications regardless of the
input NOX emission rate or other parameters. In addition, we
note that the emission rate analyzed by Wyoming, 0.07 lb/MMBtu, was on
a 30-day rolling average basis, not an annual basis. Regardless, we
agree that SCR can in most cases achieve a performance rate of 0.05 lb/
MMBtu on an annual basis. (See the section IV.C.4 of this document for
more information regarding the control effectiveness of SCR). We have
revised the SCR costs for the Laramie River Station units accordingly.
Comment: The final state BART determination sets NOX
emission limits of 0.21 lb/MMBtu, 30-day average, and related lb/hour
and tons/year limits. However, EPA does not analyze these limits and
find they are unreasonable. It analyzes instead a NOX
emission limit of 0.23 lb/MMBtu, which is not the actual final BART
limit but rather an initial limit in the BART permit that was appealed
and was changed in the settlement of that appeal and incorporated in
the final SIP. Therefore, EPA's disapproval pertains to a BART limit
that is different than the actual BART limit. Using the wrong BART
limit is arbitrary and unreasonable.
Response: In our revised cost and visibility analyses for the
Laramie River Station BART units, we have addressed the issue described
by the commenter. However, we have not analyzed the 0.21 lb/MMBtu limit
directly as it is assessed on a 30-day rolling average basis. Instead,
as described above, we have used the actual annual emission rate of
0.19 lb/MMBtu demonstrated since the installation of new LNBs and OFA.
Our approach is consistent with the BART Guidelines which state: ``. .
. you will estimate the anticipated annual emissions based upon actual
emissions from a baseline period.'' 70 FR 39167.
Comment: The purpose of the regional haze program is to improve
visibility in Class I areas. The amount of emission reductions by
itself, without any connection to visibility improvement, is irrelevant
because without some connection to visibility improvement we cannot
judge the significance of such reductions in light of the ``overarching
purpose of the regional haze program'' to protect visibility in Class I
areas. Since EPA acknowledges that SNCR would not improve visibility by
a perceptible amount, the amount of NOX emission reductions
standing alone does not further the purpose of the program.
Response: We disagree that the visibility improvements for Laramie
River Station are de minimis or too small to justify the expense of
requiring controls. The BART Guidelines are clear that it is not
necessary for the visibility improvement of a particular control option
to be above the perceptible threshold: ``Even though the visibility
improvement from an individual source may not be perceptible, it should
still be considered in setting BART because the contribution to haze
may be significant relative to other source contributions in the Class
I area. Thus, we disagree that the degree of improvement should be
contingent upon perceptibility. Failing to consider less-than-
perceptible contributions to visibility impairment would ignore the
CAA's intent to have BART requirements apply to sources that contribute
to, as well as cause, such impairment.'' 70 FR 39129.
EPA followed the BART Guidelines in determining what BART was for
each unit, taking into account the five factors, including visibility
improvement and the cost effectiveness of controls (which includes an
assessment of the dollars per ton removed).
2. Jim Bridger Units 1-4
a. NOX BART Determination
Comment: In estimating the annual cost-effectiveness of the LNB/
SOFA+SCR option, Wyoming assumed 0.07 lb/MMBtu on an annual average
basis. Based on the 0.026 lb/MMBtu NOX emission rate
predicted for the LNB/SOFA option, and the 0.20 lb/MMBtu annual
emission rates demonstrated by all four Bridger units, outlet emissions
at 0.07 lb/MMBtu represent only a 65%-73% SCR control efficiency as
opposed to the generally-accepted 90%. Wyoming has not provided any
documentation or justification to support the higher emission rates
used in its analyses. In other recent BART actions, EPA has determined
that SCR can achieve 0.05 lb/MMBtu on an annual basis. Such an
underestimate at Bridger biases the cost-benefit analysis against SCR
and is inconsistent with other EPA analyses.
Response: The commenter has incorrectly assumed that a 90% control
[[Page 5183]]
efficiency can be achieved in all SCR applications regardless of the
input NOX emission rate or other parameters. In addition, we
note that the emission rate analyzed by Wyoming, 0.07 lb/MMBtu, was on
a 30-day rolling average basis, not an annual basis. Nonetheless, we
agree that SCR can, in most cases, achieve a performance rate of 0.05
lb/MMBtu on an annual basis.
Comment: Based on an evaluation of the rolling 30-boiler operating
day average NOX emission rates from Jim Bridger Units 1-4
over the period of January 1, 2011 through March 31, 2013 with
emissions data available in EPA's CAMD, a NOX limit of 0.07
lb/MMBtu on a rolling 30-boiler operating day basis would only require
Jim Bridger Units 1-4 to achieve 66-68 percent NOX removal
across the SCR systems. The commenter asserted that a 0.05 lb/MMBtu
NOX emission limit applicable on a rolling 30-boiler
operating day average basis would only require 75-77 percent
NOX removal across the SCR, which the commenter believes is
readily achievable. (The commenter's arguments regarding the achievable
level of NOX control with SCR are summarized elsewhere in
this document.)
Response: We have addressed the control effectiveness of SCR above
in section V.C.3 above.
Comment: EPA's reliance on selected ``affordability'' language in
its BART Guidelines does not support EPA's decision to exempt all Jim
Bridger from SCR BART requirements. First, Congress established five
factors--no more--that EPA must consider when making source-by-source
BART determinations. 42 U.S.C. 7491(g). Applying those five factors
alone, EPA determined that SCR was BART for all four Bridger Units. 78
FR 34756. By considering the ``affordability'' of BART controls across
PacifiCorp's entire fleet, EPA has arbitrarily relied on factors which
Congress has not intended it to consider. Motor Vehicle Mfrs. Ass'n v.
State Farm Mut. Auto. Ins. Co., 463 U.S. 29, 43 (1983f); Pac. Coast
Fed'n of Fishermen's Ass'ns, Inc. v. Nat'l Marine Fisheries Serv., 265
F.3d 1028, 1034 (9th Cir. 2001); see also North Carolina v. Envtl.
Prot. Agency, 531F.3d 896, 906 (D.C. Cir. 2008) (standard of review is
the same under the APA and the CAA, 42 U.S.C. 7607).
Response: We disagree with the commenter that when considering the
five factors alone, SCR is BART on all the Jim Bridger units. As
discussed in section III.B.6 above, when considering the five factors,
we find it unreasonable to require SCR as BART on these two units and
instead we are approving the State's LTS for (all four or Units 1 and
2) the Jim Bridger units. We are not relying on the affordability
analysis in making this final determination.
Comment: 40 CFR part 51, Appendix Y, section IV.E.3 makes clear
that the affordability analysis should be limited to the economic
impact of the BART unit at issue--not to a utility's fleet-wide BART
obligations as a whole. EPA's application of this language to
PacifiCorp's BART obligations at other power plants is improper. In
addition, the BART Guidelines establish a very narrow test for applying
the affordability language, which is whether requiring installation of
the control technology would ``have a severe impact on plant
operations.'' 40 CFR part 51, app. Y, section IV.E.3. In such
circumstances, the BART Guidelines suggest that EPA prepare ``an
economic analysis that demonstrates, in sufficient detail for public
review, the specific economic effects, parameters, and reasoning.'' EPA
has not prepared an economic analysis demonstrating the specific
economic, parameters, and reasoning for its decision to exempt the Jim
Bridger facility from further BART controls. Instead, EPA simply
concludes that ``it would be unreasonable to require any further
retrofits at this source within five years of our final action'' based
on PacifiCorp's BART obligations at other facilities. 78 FR 34756.
Further, PacifiCorp has not presented evidence that installation of SCR
at each Bridger unit within the first regional haze planning period
would cause any noticeable economic impact, let alone ``severe''
impact, such a shutdown of one or all of the units.
Response: As discussed in more detail in a response to another
comment below, we agree that PacifiCorp has not provided sufficient
evidence to show that the installation of SCR at the Jim Bridger units
within five years after our final action would cause a severe economic
impact. We are basing our decision to not require SCR for BART based on
our weighing of the five factors.
Comment: The BART Guidelines also suggest that if the agency grants
an affordability exemption from the best level of control, it must then
select a ``slightly lesser degree of control.'' 40 CFR part 51, app. Y,
section IV.E.3. EPA's proposal does not require any additional level of
control under BART. Instead, EPA's 2013 re-proposal selects the pre-
existing LNB/OFA as BART for each unit. EPA's choice of LNB/OFA as BART
does not even represent the ``second best'' control technology for
eliminating NOX related visibility impairment--which would
be SNCR. 78 FR 34756 (Table 13).
Response: As stated above, we are not basing our BART determination
for Jim Bridger Units 1 and 2 on an affordability argument.
Comment: The BART Guidelines ``affordability'' language recommends
that states (or EPA) consider ``whether other competing plants in the
same industry have been required to install BART controls if this
information is available.'' 40 CFR part 51, app. Y, section IV.E.3.
This provision suggests that SCR requirements should be applied
consistently among competing utility companies. EPA's exemption of
PacifiCorp from SCR obligations at the Jim Bridger units is
inconsistent with its actions at other competing utility companies with
large coal fleets, to which EPA has not offered ``affordability''
exemptions from SCR requirements. For example, EPA has required Salt
River Project, a competing utility, to install SCR on numerous coal-
plant units in its fleet, including Coronado and Navajo (Arizona),
Craig and Hayden (Colorado) and Four Corners (New Mexico). Each of
EPA's BART determinations for these plants requires installation of SCR
as BART within the mandated five-year implementation deadline.
EPA's 2013 re-proposal for Jim Bridger exempts the plant from both
the SCR requirement and the five-year implementation deadline,
potentially giving PacifiCorp an advantage over the competing
utilities. Thus, EPA's 2013 re-proposal rule is not only inconsistent
with its own BART Guidelines, it is competitively unfair.
Response: We agree that other utility companies have had to install
SCR within the five year BART window and that evidence provided by
PacifiCorp does not support delaying controls on Jim Bridger Units 1
and 2 until 2022 and 2021, respectively. Nonetheless, as stated
earlier, we are no longer basing our BART determination for Jim Bridger
Units 1 and 2 on an affordability argument.
Comment: We are very familiar with the ``affordability'' provisions
of the BART Guidelines and have dealt with this issue in Arizona
(Apache power plant) and Washington (Alcoa's Intalco primary aluminum
smelter). In both of those cases, the company requesting the
affordability exemption from BART provided extensive documentation
(much of it confidential) to EPA and the FLMs to support its request.
It was only after a thorough review by EPA that the affordability
exemptions were approved. In this case, it appears that the only
information presented by PacifiCorp to
[[Page 5184]]
support its request is its ``assertions'' dated July 12, 2012. We
believe that a more rigorous analysis is necessary in order for EPA,
FLMs, and the public to be assured that the additional time being
proposed by EPA is necessary and appropriate. For example, an important
part of such an analysis would be the ``installation schedule'' that
PacifiCorp has designed in order to minimize the number of units that
are out of service system-wide for installation of emissions controls
at any one time. Currently, the only schedule available in the docket
is the July 2012 letter from PacifiCorp to EPA in which PacifiCorp
simply reiterates the dates proposed for its ``Installation
Requirements.''
Response: As stated in other responses to comments, we agree that
the information provided by PacifiCorp was not sufficient to support
the delay of SCR controls on Jim Bridger Units 1 and 2, but we are not
relying on that information in our BART determination.
Comment: EPA's proposal for Jim Bridger Units 1 and 2 is a ``do
nothing'' BART determination. Although the Agency claims that it is
proposing to approve the State's proposal to require the use of LNBs
for Units 1 and 2 and for both units to meet an emission rate of 0.28
lb/MMBtu over a 30-day rolling period, this emission rate is actually
higher than what Units 1 and 2 are currently emitting and worse, does
not reflect the presumptive BART limits set forth in 40 CFR part 51,
Appendix Y. Most significantly, it defies the statutory intent of
Congress in establishing the regional haze program under the CAA.
According to EPA's CAMD Web site, both Units 1 and 2 already
consistently achieve 30-day rolling average NOX emissions
lower than 0.20 lb/MMBtu. The data illustrates that Jim Bridger Units 1
and 2 consistently achieve NOX emission rates below 0.20 lb/
MMBtu on a monthly basis and have done so since 2010. To this end, the
definition of BART explicitly states that it must represent a
``reduction'' in each pollutant that causes or contributes to
visibility impairment. See 40 CFR 51.301 (setting forth definition of
BART).
Furthermore, although a state must take into account the five
factors set forth under 42 U.S.C. 7491(g)(2), nothing in the CAA or the
EPA's regulations implementing the regional haze program suggest or
remotely imply that a state could allow emission increases as BART.
Accordingly, EPA must, at a minimum, disapprove of Wyoming's
NOX BART determinations for Jim Bridger Units 1 and 2 and
adopt a FIP that establishes BART limits that are consistent with the
CAA and that represent actual emission reductions.
Response: We disagree with the commenter that BART is an emission
limit of 0.07 lb/MMBtu at Jim Bridger Units 1 and 2 within five years
of our final action. As discussed previously, based on our weighing of
the five factors, we do not find it reasonable to require SCR for BART
on Jim Bridger Units 1 and 2 and instead we are approving the State's
LTS for these units.
Comment: The need to promulgate a FIP is underscored by the EPA's
own BART guidelines. According to those guidelines, tangentially fired
boilers burning subbituminous coal, such as Jim Bridger Units 1 and 2,
are presumed to be able to cost-effectively meet a NOX
emission rate of 0.15 lb/MMBtu on a 30-day rolling average basis. See
40 CFR part 51, Appendix Y, Table 1. EPA's claim that it would not be
cost-effective to meet an emission rate below 0.28 lb/MMBtu as BART for
Units 1 and 2 is therefore undercut by the Agency's own extensive
analysis and conclusion that a 0.15 lb/MMBtu rate is presumed to be
appropriate. Tellingly, the EPA nowhere in its proposed rule analyzes
or addresses why a 0.28 lb/MMBtu rate is appropriate in light of the
Agency's own presumptive BART limits for NOX emissions from
tangentially-fired boilers burning subbituminous coal.
Response: We disagree with the commenter's assertion that our
approval of non-presumptive BART emission limits for Jim Bridger Units
1 and 2 is flawed. In the BART Guidelines EPA explained that:
For coal-fired EGUs greater than 200 MW located at greater than
750 MW power plants and operating without post-combustion controls
(i.e. SCR or SNCR), we have provided presumptive NOX
limits, differentiated by boiler design and type of coal burned. You
may determine that an alternative control level is appropriate based
on a careful consideration of the statutory factors. For coal-fired
EGUs greater than 200 MW located at power plants 750 MW or less in
size and operating without post-combustion controls, you should
likewise presume that these same levels are cost-effective. You
should require such utility boilers to meet the following
NOX emission limits, unless you determine that an
alternative control level is justified based on consideration of the
statutory factors.\231\
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\231\ 40 CFR Part 51, Appendix Y, section IV.E.5.
Therefore, the presumptive emission limits in the BART Guidelines are
rebuttable, and the five statutory factors enumerated in the BART
Guidelines provide the mechanism for establishing different
requirements. Specifically, as explained in the preamble to the BART
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Guidelines:
If, upon examination of an individual EGU, a State determines
that a different emission limit is appropriate based upon its
analysis of the five factors, then the State may apply a more or
less stringent limit.\232\
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\232\ 70 FR 39132.
Thus, the establishment of presumptive BART emission limits does
not preclude states or EPA from setting limits that differ from those
presumptions, even where the control technology is the same as that
associated with the presumptive limits (in this case, combustion
controls). The five-factor analysis performed by Wyoming demonstrates
that, because of the nature of the coal fired at these units, the
presumptive limit of 0.15 lb/MMBtu is not attainable. Wyoming supported
this conclusion with information from an established vendor of
combustion controls.\233\ We concur with those conclusions and find
that Wyoming's BART emission limits for Jim Bridger Units 1 and 2 were
established in a manner consistent with the BART Guidelines.
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\233\ Wyoming Department of Environmental Quality Air Quality
Division, BART Application Analysis AP-6040, May 28, 2009, pages 7-
9.
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Comment: EPA's proposal is fundamentally flawed because it makes a
mockery of the CAA. Despite acknowledging that BART should be the
installation of SCR and compliance with a 0.07 lb/MMBtu emission rate
for Units 1 and 2, the EPA determined that, when considering the cost
of such controls, they would not be reasonable. Certainly, the CAA
allows the EPA to consider the ``cost of compliance'' in setting BART
(42 U.S.C. 7491(g)(2)), but the CAA does not allow the EPA to
completely avoid requiring BART based on cost considerations. Here,
EPA's proposal to approve Wyoming's SIP with regards to BART for Jim
Bridger Units 1 and 2 amounts to a proposal to require nothing (if not
a proposal to allow an increase in emissions). In essence, EPA's
proposal amounts to a determination that BART is not required for Jim
Bridger Units 1 and 2, even though Congress clearly stated that these
coal-fired EGUs are subject-to-BART. Although Congress allowed the EPA
to consider costs in establishing BART, the EPA cannot use costs as a
reason to completely forego requiring BART. Put another way, the EPA
cannot defeat Congress' intent to require BART by cobbling together an
interpretation of the CAA that effectively nullifies the regional haze
BART requirements under the Act.
[[Page 5185]]
Response: We disagree with the commenter. As discussed elsewhere,
we are basing on approval of the State's SIP on a weighing of the five
BART factors, including costs and visibility improvement.
Comment: EPA's proposal for Jim Bridger Units 1 and 2 ``does not
meet a test for being `better than BART'. . . [because] [t]he
accelerated installation of BART at Bridger Units 3 and 4 does not
offset the increased emissions from delaying SCR installation at
Bridger Units 1 and 2 beyond the normal five-year BART window.'' To
date, EPA has failed to make any demonstration that its 2013 Proposal
would ``achieve greater reasonable progress than would be achieved
through the installation and operation of BART.'' 40 CFR 51.308(2)(i).
Moreover, EPA's proposal also fails to comply with the ``better than
BART'' regulatory requirement mandating that ``all necessary emission
reductions take place during the period of the first LTS for regional
haze'' which concludes at the end of 2017. Id. section 51.308(b),
(e)(2)(iii). Accordingly, EPA's proposal has not satisfied the
regulatory requirements for a ``better than BART'' alternative.
Response: We agree that EPA's proposal does not meet a test for
being better than BART but have not suggested such a concept in our
proposed or final rulemaking actions.
Comment: EPA's proposed action on the Wyoming 308 regional haze SIP
requested comments on whether to require installation of BART controls
on Jim Bridger Units 1 and 2 by 2021-2022 rather than within the
legally required five-year timeframe mandated by the regional haze
regulations. 77 FR 33054. EPA is taking comment on the alternative
timeline for SCR installation in response to PacifiCorp's claim that
``the schedule for installation of emission control devices envisioned
in [EPA's BART proposal] would be excessively costly and would pose
service interruption risks for electrical energy customers over a large
part of the region.'' Recent admissions by a PacifiCorp official in a
separate Wyoming Public Service Commission proceeding undermines
PacifiCorp`s arguments. PacifiCorp argued to the Wyoming Public Service
Commission that procurement and installation of multiple SCRs creates
both a cost and time savings, not an increase at Jim Bridger Units 3
and 4. This fact is also true for installation of SCRs at Jim Bridger
Units 1 and 2. This PacifiCorp admission is further proof that EPA
should not permit PacifiCorp to delay installation of SCRs at Jim
Bridger Units 1 and 2 and instead must require compliance within five
years as is required by the BART regulations.
Response: We have responded to this comment in other responses.
Comment: EPA is taking comment on the alternative timeline for SCR
installation in response to PacifiCorp's claim that the schedule for
installation of emission control devices envisioned in EPA's BART
proposal would be excessively costly and would pose service
interruption risks for electrical energy customers over a large part of
the region. EPA acknowledges that BART for all the units at Jim Bridger
is SCR when the units are considered individually based on the five
factors. However, EPA suggests that a different BART determination
under the alternative approach is lawful if the five factors are
considered across all the units in the PacifiCorp system. Not so. BART
is a source-by-source determination.
Response: We have responded to this comment in other responses.
Comment: Considerations of PacifiCorp's fleet size and cumulative
costs are outside the five-factor analysis for BART. Furthermore,
PacifiCorp's concern about the feasibility of installing BART controls
over its large fleet is unfounded. With proper planning, there is no
reason to expect excessive costs or service interruption due to BART
requirements. Indeed, PacifiCorp's large number of EGUs would appear to
give PacifiCorp the unique ability to avoid service disruptions by
maintaining adequate capacity from operating units while other units
are offline. Further, other utilities have installed SCR systems on
multiple units within very short periods of time.
PacifiCorp's ability to install SCR on multiple units is also not
constrained by the availability of SCR systems. In response to
questioning of whether PacifiCorp has had any difficulties procuring or
installing SCR systems, particularly an SCR for its Naughton Unit 3
facility, PacifiCorp stated it had received four proposals from SCR
system suppliers and as such did not experience notable difficulties
procuring and obtaining the SCR system. EPA should not modify its BART
proposal for Jim Bridger Units 1 and 2 based on PacifiCorp's
unsupported claims of hardship.
Response: We have responded to this comment in other responses.
Comment: The EPA's re-proposed Wyoming haze plan reiterates EPA's
prior finding that BART is SCR for each Jim Bridger unit considered
individually (78 FR 34756). Based on the EPA's five-factor
NOX BART analyses for Jim Bridger Units 1-4, the EPA must
find that SCR is BART to meet a NOX emission rate of 0.05
lb/MMBtu on all four units.
The EPA's cost-effectiveness analyses identified costs for SCR on
all four Bridger Units that are within the range that EPA has
identified as reasonable for other units, including in this same
proposal. 78 FR 34754-57 (SCR cost-effectiveness of $2,393/ton on Jim
Bridger Unit 1, $3,015/ton on Unit 2, $2,961/ton on Unit 3, and $2,492/
ton on Unit 4) as compared with, e.g., 78 FR 34776 (finding cost-
effectiveness of $3,600/ton to $3,900/ton for SCR on Laramie River
Units 1-3 to be ``within the range of what EPA has found reasonable for
BART in other SIP and FIP actions''). However, the EPA's estimate of
costs is significantly inflated, and the true costs are even lower than
EPA found because the EPA used unjustified ``retrofit factors,''
interest rate, and auxiliary power costs. The recalculation of costs
using what the commenter believes are corrected inputs resulted in
significantly lower SCR costs of $1,801 to $1,959/ton at all four
Bridger units. On this basis, SCR is extremely cost effective on these
units. SCR on these units would afford substantial visibility benefits.
The EPA has no basis in the BART factors, including the important
factors of compliance costs and visibility improvement, to reject SCR
as BART on Bridger Units 1-4.
Response: As discussed elsewhere, we have responded to the
commenter's points about how costs are calculated for the BART units.
Regardless, we determined that SCR was not reasonable for BART based on
our weighing of the five factors.
Comment: The EPA's 1st Proposal from its June 2012 Proposal/2013
Proposal in the Alternative, which would approve Wyoming's
NOX emission limits and SCR compliance timeframes for Jim
Bridger Units 3 and 4 and would require Jim Bridger Units 1 and 2 to
install SCR within five years of EPA's final action on the Wyoming
regional haze plan, would result in lower NOX emissions on
an annual basis than any of EPA's other NOX proposals at the
Jim Bridger Power Plant. This schedule also likely reflects the most
economical installation of SCR at all four of the Jim Bridger units
because the engineering for SCR installation, including the design of
the construction phase, can all be done during the same time frame, the
construction equipment can remain on-site for the duration of the
installations, and much of the installation work can be done
[[Page 5186]]
simultaneously, which will save on labor and construction equipment.
There are numerous examples of installations of multiple SCRs at
numerous units at the same power plant site over short timeframes,
including: (1) W.A. Parish Units 5-8 (SCRs installed over 2003-2004);
(2) All four units of the Big Bend power plant (SCRs installed during
2007-2010); (3) Units 1-5 of the Clifty Creek power plant (SCRs
installed 2002-2003); (4) Winyah Units 1-4 (SCRs installed in 2005);
(5) Over the period of 2001-2006, TVA has installed SCRs at 18 units at
four power plants. On this basis, the number and timing of SCR
installations required at PacifiCorp plants as a result of
NOX BART determinations can be accomplished, as it has been
done before.
Response: As stated above, we find that PacifiCorp has not
presented sufficient evidence that the economic effects of installation
of SCR on Jim Bridger Units 1 and 2 within five years would affect the
viability of continued plant operations, but based on weighing of the
five factors, we find that it is not reasonable to require SCR for
BART.
Comment: We agree with EPA that Wyoming's proposal to require
installation of SCR in 2021 and 2022 as part of Wyoming's LTS does not
satisfy the CAA or its implementing regulations. Having determined that
SCR plus LNBs/SOFA is the best system of continuous emission control,
is cost effective, and will result in significant visibility
improvement, EPA is required to find that the controls are BART. 40 CFR
51.308(e)(i)(2)(A). Under the RHR, BART must be installed ``as
expeditiously as practicable, but in no event later than five years
after approval of the implementation plan revision.'' 40 CFR
51.308(e)(iv). Thus, EPA lacks discretion to approve Wyoming's proposal
to require PacifiCorp to install BART technology beyond the five-year
time frame.
Response: See responses above.
Comment: PacifiCorp submitted comments in support of delaying
controls on Jim Bridger Units 1 and 2 until 2022 and 2021 respectively.
(EPA issued a Notice of Data Availability pertaining to this
information on July 24, 2012. 77 FR 43205). The main points raised in
their comments are as follows: \234\
---------------------------------------------------------------------------
\234\ See July 12, 2012 comments from PacifiCorp in the docket.
---------------------------------------------------------------------------
Because of the size and multi-state nature of its
generation fleet, PacifiCorp and its customers are unreasonably
impacted by the RHR. PacifiCorp provides regulated electric service to
more than 1.7 million customers in California, Idaho, Oregon, Utah,
Washington and Wyoming with a net system capacity of 10,597 megawatts.
PacifiCorp operates 75 generating units across the western U.S.
PacifiCorp owns and operates 19 coal-fueled generating units in Utah
and Wyoming, and owns 100% of Cholla Unit 4, a coal-fueled generating
unit in Arizona. In addition, PacifiCorp has an ownership interest in
Craig Units 1 and 2 and Hayden Units 1 and 2 in Colorado.
As evidenced by the emission reduction projects which
PacifiCorp has already installed in accordance with the Utah and
Wyoming regional haze SIPs, PacifiCorp is not opposed to making
emission reductions that are cost effective for its customers and that
achieve environmental benefits, as required by law. PacifiCorp has
undertaken projects to comply with the Utah and Wyoming SIPs at a cost
of approximately $1.3 billion (PacifiCorp's share of $1.4 billion of
total project costs) between 2005 and 2011. Those projects, in
conjunction with projects completed through 2012, have reduced
emissions of SO2 by approximately 58% and emissions of
NOX by approximately 46%.
Just as modeled visibility improvements associated with
PacifiCorp's emission reduction projects do not stop artificially at a
state border, EPA's analysis of the impacts of its proposed FIP for a
large, multi-state system like PacifiCorp's should not be limited to
only those facilities and customers located within Wyoming's borders.
EPA's actions impacting large, multi-state systems in one state must
also consider the cumulative impacts of all of its actions in all other
states that affect the same system.
Given the number of facilities operated by PacifiCorp and
the facilities in which the company has an ownership interest in and is
required to pay costs for the installation of regional haze-related
controls, accelerated and additional controls under the proposed FIP
result in approximately $500 million of additional capital expenditures
plus an incremental annual cost of $16-24 million to operate those
controls in the next five years. In addition, an EPA proposal for
stringent control requirements in Utah (i.e., SCR) within five years
would add approximately $750 million in capital expenditures, plus
approximately $7 million to $9 million annually in operating costs and
approximately $4 million annually for catalyst replacement projects.
All of these costs will be put on the backs of PacifiCorp and its
customers in an extremely short-time frame.
In addition to the regional haze requirements,
PacifiCorp's coal-fueled generating fleet, including the BART-eligible
units, must accommodate controls for compliance with the Mercury and
Air Toxics Standards (MATS) during the same timeframe. While the
scrubbers and baghouses already installed at many of the PacifiCorp
facilities pursuant to the Utah and Wyoming regional haze SIPs position
the company well to comply with the acid gas and non-mercury metals
limits under the MATS requirements, additional work will be necessary
to comply with the mercury emission limits by April 2015.
PacifiCorp's customers cannot absorb increasing
environmental costs. To accommodate, among other cost increases, the
costs of the environmental controls already installed on PacifiCorp's
coal-fueled generating facilities, PacifiCorp has filed with its
utility regulatory authorities annual cases to increase customer rates.
PacifiCorp's customers have consistently participated in these cases to
express concerns regarding increases in electric rates. While EPA may
view its proposal to accelerate the installation of controls and
require additional controls at PacifiCorp's facilities as just another
utility complaining to avoid the consequences of large investments in
controls, EPA's proposal has a very real impact on customers.
As a regulated utility, PacifiCorp has a legal obligation
to supply reliable electric service at reasonable rates as set by state
utility commissions; it also has a legal requirement to supply its
customers as much electricity as they want, when they want it. While
the installation of emissions controls on multiple units in a short
period of time creates substantial challenges from a project management
perspective, these challenges are exacerbated by increased risk factors
that jeopardize PacifiCorp's ability to meet its underlying utility
obligations and challenge the reliability of the system.
When considered independently from other environmental
requirements, the retrofits required under either regional haze
compliance scenario are not anticipated to impose undue stress on the
national supply chain for specialized labor, materials, and equipment.
However, analyses of compliance with the MATS have raised concerns that
requiring much of the U.S. coal fleet to retrofit or retire in a three
to five year-time frame (partially overlapping the compliance time
period under the regional haze program) will
[[Page 5187]]
challenge the equipment construction industry.
Wyoming and EPA are legally required to consider the
economic and system impacts on PacifiCorp and its customers. As EPA's
BART Guidelines explain: ``There may be unusual circumstances that
justify taking into consideration the . . . economic effects of
requiring the use of a given control technology. These effects would
include effects on product prices . . . Where these effects are judged
to have a severe impact on plant operations you may consider them in
the selection process, but you may wish to provide an economic analysis
that demonstrates, in sufficient detail, for public review, the
specific economic effects, parameters, and reasoning.'' 70 FR 39171.
Given the large number of BART impacted units owned by PacifiCorp in
different states, these unusual circumstances justify Wyoming's BART
actions on PacifiCorp's facilities and PacifiCorp's customers.
Response: PacifiCorp argues that springtime scheduling of the unit
outages and outage extensions needed for ``tie-in'' of retrofitted
controls could challenge system reliability in certain years--in
PacifiCorp's forecast, power demand plus reserves would temporarily
exceed available supply. EPA believes that this forecast is unrealistic
because PacifiCorp constrains itself almost entirely to use of its own
generation supplies (ignoring other available generators in its region)
and limits its assessment to springtime-only outages in its system-wide
outage planning examples. PacifiCorp indicates that spring outages are
economically preferred due to the historical availability of cheap
hydro replacement power and the typically higher alternative costs of
purchased replacement power at other times. However, PacifiCorp
provides no information on the availability or net cost of replacement
power to meet demand, nor does PacifiCorp identify any alternative
retrofit outage schedules. This is a significant omission because
alternative retrofit outage schedules that avoid reliability issues
through non-coincident temporary uses of purchased power, even if such
temporary power purchases may cost more than power typically provided
by the facilities experiencing an outage, might have a very small
levelized net retail cost impact when applied to customers system-wide.
In short, PacifiCorp ties its own hands in its provided analysis,
ignoring proven and cost-effective strategies for maintaining electric
reliability to allow facility upgrades in a timely fashion.
EPA notes that PacifiCorp overstates the purported regulatory
burden on its generating resources by claiming that the company ``has
not yet identified a viable control suite that will allow it to comply
with the [Mercury and Air Toxics Standards, or MATS] provisions at the
Carbon plant in Utah. As a result, while not finally determined, it is
anticipated that Carbon Units 1 and 2 will be required to be shut down
in the 2015 timeframe, resulting in the loss of 172 megawatts of
generation from PacifiCorp's system.'' Such an assumption is unfounded
and ignores the EPA's clear explanation in the final MATS that under
the CAA, state permitting authorities can also grant sources an
additional year as needed for technology installation. EPA expects this
option to be broadly available. EPA is also providing a pathway for
reliability critical units to obtain a schedule with up to an
additional year to achieve compliance. This pathway is described in a
separate enforcement policy document.\235\ As a result, the comment
does not identify any specific conflict between MATS compliance
planning at the Carbon facility and regional haze compliance planning
at the Jim Bridger units at issue in this rule.
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\235\ Memorandum from Cynthia Giles, Assistant Administrator of
the Office of Enforcement and Compliance Assurance, ``The
Environmental Protection Agency's Enforcement Response Policy for
Use of Clean Air Act Section 113(a) Administrative Orders in
Relation to Electric Reliability and the Mercury and Air Toxics
Standard'' (Dec. 16, 2011).
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In developing their argument, PacifiCorp borrows a ``WetFGDeq''
concept that EPA used in its nation-wide analysis of the feasibility of
retrofitting all controls that might be needed for timely compliance
with MATS. PacifiCorp uses EPA's nationally applicable WetFGDeq concept
to compare annual WetFGDeq MW amounts of the limited site-specific
retrofit activity that PacifiCorp has actually conducted during the
past two decades, and might conduct in the future under the SIP, to the
annual amount that they might have to conduct in the future under the
proposed FIP. Based on this comparison, PacifiCorp states the following
(see page 20 of 23; also see Figure 8 of PacifiCorp's July 12, 2012
comments): ``The differences between the SIP Scenario and the
Aggressive BART Scenario are fairly substantial on an equivalent Wet
FGD basis. In the SIP Scenario, only one year exceeds the 2010-2011
levels of retrofit investment (of about 225 MW/year), while retrofits
placed in service in 2017 (675 MW) substantially exceed the previous
historic maximum of 475 MW by 200 MW and two years are above the 2010-
2011 level. The control installation requirements under the EPA
Aggressive BART Scenario would result in more work, less time, and
increased costs.''
EPA does not disagree that the proposed FIP may entail more
PacifiCorp project management and construction effort (in one year,
2017) than the SIP would require, or than PacifiCorp has actually
experienced as an individual company in the past. However, EPA does not
consider the relatively small absolute amounts of the differences (200-
300 MW) to be a serious obstacle for any large utility, given a bevy of
retrofit experience of this magnitude by like companies in the past, on
similar schedules.
Comment: In making any BART determinations on a large, multi-
jurisdictional system such as PacifiCorp's, the regulating agency must
consider the broad scope of the impacts of its decisions on customers
and generating system reliability as a whole. Wyoming considered these
factors in developing its regional haze SIP: ``The Division believes
that the size of PacifiCorp's fleet of coal-fired units presents unique
challenges when reviewing costs, timing of installations, customer
needs, and state regulatory commission requirements. Information has
been supplied by PacifiCorp elaborating on additional factors to be
considered in PacifiCorp's BART determination (see PacifiCorp's
Emissions Reductions Plan in Chapter 6 of the Wyoming technical support
document).''
Wyoming's consideration of these factors was appropriate. While
PacifiCorp agrees with EPA's proposed conclusions regarding the
reasonableness and timing of installation of controls at Jim Bridger
Units 1 and 2, EPA's focus on affordability impermissibly fails to
consider the unusual circumstances and broader impacts of its action on
PacifiCorp's other BART Units. EPA's selection of SCR controls at
Naughton Units 1 and 2 and at Dave Johnson Unit 3 will affect the
viability of continued unit operations. Installation of SCR controls at
these three units, particularly given the cost of controls and their
remaining useful life, create such ``unusual circumstances'' that
justify taking into consideration the conditions of the plant and the
economic effects of requiring the use of a given control technology.
The timing and reasonableness of the eight SCR and two SNCR and
LNBs required in EPA's proposed action must
[[Page 5188]]
be considered in the context of the additional controls required at
PacifiCorp's units in Arizona (Cholla Unit 4 with SCR required by 2017)
and its share of units in Colorado (Hayden Unit 1 with SCR in 2015,
Hayden Unit 2 with SCR in 2016, Craig Unit 1 with SNCR in 2017 and
Craig Unit 2 with SCR required in 2016) and the potential for
additional controls required at four of PacifiCorp's BART-eligible
units in Utah within five years after final action. EPA's failure to
consider the ``unusual circumstances'' contemplated under its Appendix
Y Guidance means the agency acted in a manner that is arbitrary and
capricious in its overall assessment (or lack thereof) of the effects
of its actions on PacifiCorp's generation fleet.
Response: See our response to the comment above.
Comment: Pursuant to 40 CFR 51.308(e), the State included
provisions in its 309(g) regional haze SIP to address BART. When
evaluating each permit application, the State determined BART for each
source by evaluating visibility control options presented in the
applications using the methodology prescribed in 40 CFR part 51,
Appendix Y.
The use of the BART guidelines contained in Appendix Y is only
required for sources located at EGUs with a total capacity greater than
750 MW, which for Wyoming were Basin Electric's Laramie River Station
and PacifiCorp's Jim Bridger and Dave Johnston plants. However, for
consistency, the State chose to follow the guidelines for all BART
sources, including those located at the trona facilities. By using the
guidelines of Appendix Y for all sources, the State established a
consistent framework for performing BART evaluations. Finally, when
selecting the ``best alternative,'' the State considered additional
impacts to both the plant and the State. Appendix Y affords the
determining authority discretion to consider additional impacts. See 70
FR at 39171.
The State's BART analysis not only considered all statutory
factors, but also considered the significant impact on energy costs to
PacifiCorp's Wyoming rate payers if the controls, including SCR, were
required to be installed in the BART timeframe of five years after SIP
approval. While the State did not have the resources to perform a
highly technical and complex analysis to quantify the potential cost
impact of requiring installation of SCR controls on all of PacifiCorp's
Wyoming fleet, additional information was provided by PacifiCorp for
public review.
In addition to identifying costs in terms of capital expenditures,
the State also considered the logistical challenges unique to
PacifiCorp. The State is not aware of any other company faced with as
many potential add-on control installations as PacifiCorp.
Additionally, the State noted potential reliability issues related to
the extended downtimes needed for the installation of SCR systems on
multiple units within the BART timeframe. The impact of taking down
large units, like Jim Bridger Units 1-4, each rated at a nominal 530
MW, for extended outages increases the possibility of power shortages,
not to mention increased power cost if PacifiCorp must purchase
additional power at spot market prices to meet demand.
Response: The commenter raises many of the same points that
PacifiCorp raised in its July 12, 2012 comments on our third proposal
in the alternative, and we have responded to the commenters points in
our response above. EPA does not find the arguments for delaying
controls put forth by PacifiCorp or the commenter to be compelling.
Comment: In making any BART determinations on a large, multi-
jurisdictional system such as PacifiCorp's, the regulating agency must
consider the broad scope of the impacts of its decisions on customers
and generating system reliability as a whole. Wyoming considered these
factors in developing its regional haze SIP: ``The State believes that
the size of PacifiCorp's fleet of coal-fired units presents unique
challenges when reviewing costs, timing of installations, customer
needs, and state regulatory commission requirements.'' Information has
been supplied by PacifiCorp elaborating on additional factors to be
considered in PacifiCorp's BART determination (see PacifiCorp's
Emissions Reductions Plan in Chapter 6 of the Wyoming Technical Support
Document). Wyoming's consideration of these factors was appropriate.
EPA's rejection of these factors was not appropriate.
Given the large number of BART impacted units owned by PacifiCorp
in different states, these ``unusual circumstances'' justify Wyoming
and EPA considering the impact of EPA's BART decision-making in the
western U.S. on PacifiCorp and its customers.
Response: We have responded to the commenter's points in our
responses above. As stated, EPA does not find the arguments for
delaying controls put forth by the State or PacifiCorp to be
compelling.
Comment: Congress has defined ``best available retrofit
technology'' as ``an emission limitation based on the maximum degree of
reduction of each pollutant subject to regulation under this chapter. .
. .'' 42 U.S.C. 7479(3). Congress also narrowly defined which sources
would be exempt from BART. Section 169A(c) of the CAA exempt fossil
fuel power plants exceeding 750 megawatts only if the ``owner or
operator of any such plant demonstrates to the satisfaction of the
Administrator that such power plant is located at such a distance from
all areas . . . that such power plant does not or will not, by itself
or in combination with other sources, emit any air pollutant which may
reasonably be anticipated to cause or contribute to significant
impairment of visibility in any such area.'' Id. at section 7491(c)(2).
Any such exemption must be agreed to by the FLMs. Id. at section
7491(c)(3). PacifiCorp has not submitted evidence demonstrating that
the Jim Bridger coal plant--with a net generating capacity of 2,120
megawatts, 78 FR 34753--will not cause or contribute to significant
visibility impairment in any Class I area. To the contrary, EPA's own
visibility modeling shows that Bridger has significant visibility
impacts at numerous Class 1 areas. 78 FR 34754-34758. As such, EPA may
not exempt the Jim Bridger plant from BART.
Response: We agree with the commenter that PacifiCorp has not
submitted any evidence that the Jim Bridger plant is located at such a
distance from all Class I areas that the plant will not, by itself or
in combination with other sources, emit any air pollutant which may
reasonably be anticipated to cause or contribute to significant
impairment of visibility in any such area.
Comment: EPA should require installation of SCR at each Jim Bridger
unit within the five-year regulatory deadline because this approach
offers the greatest visibility improvement.
Response: See responses above.
Comment: EPA proposes that Wyoming's determination of
NOX BART for Jim Bridger units 1 and 2 as new LNB plus OFA
is reasonable and that it would be unreasonable of the EPA to require
any further retrofits at these units within five years of EPA's final
action. 78 FR 34756. The State supports EPA's proposed approval of
NOX BART as LNB plus OFA for Jim Bridger Units 1 and 2. EPA
also proposes to approve the State's LTS of NOX control for
Jim Bridger Units 1 and 2 as the SCR-based emission rate of 0.07 lb/
MMBtu with compliance dates of December 31, 2021, for Unit 2 and
December 31, 2022, for Unit 1.
Based on facts PacifiCorp raised concerning the additional
requirements
[[Page 5189]]
in the proposed FIP for Wyoming, the finalized FIP for Arizona, and the
possibility of additional requirements in a future FIP or SIP for Utah,
the additional time allowed PacifiCorp to install controls under the
State's LTS on Jim Bridger Units 1 and 2 is warranted under the
affordability provisions in the BART Guidelines. 40 CFR part 50, App.
Y, section IV(E)(3); see also 78 FR 34756. Wyoming therefore supports
EPA's proposed approval.
Response: We disagree with the points raised by the commenter in
the second paragraph and have addressed their points in previous
responses to comments. Nonetheless, we are approving the State's SIP
for Jim Bridger Units 1 and 2.
Comment: Wyoming strongly urges EPA to stand by its proposed
approval of Wyoming's SIP requiring Jim Bridger Unit 1 to meet the 0.07
lb/MMBtu emission rate prior to December 31, 2021 and Unit 2 to meet
the 0.07 lb/MMBtu emission rate prior to December 31, 2022. However,
Wyoming encourages EPA to approve Wyoming's LTS for Jim Bridger Units 1
and 2 as submitted, rather than approve only the SCR portion, in order
to preserve future flexibility for ensuring adequate emission controls.
Response: We agree with this comment to the extent that the
regulatory requirements we are adopting for monitoring, recordkeeping,
and reporting only require that Jim Bridger Units 1 and 2 meet an
emission limit of 0.07 lb/MMBtu on a 30-day rolling average. Our
regulatory language does not require PacifiCorp to install SCR to meet
these limits. EPA is approving Wyoming's LTS for Jim Bridger Units 1
and 2 as submitted.
Comment: EPA acted arbitrarily by not evaluating SNCR for the Jim
Bridger units. EPA's proposed regional haze FIP is defective because
EPA did not follow the BART Guidelines when conducting a five-factor
analysis for potential BART NOX controls. As the BART
Guidelines explain, states (and EPA when it substitutes itself for the
state) must evaluate ``the control effectiveness of all the technically
feasible control alternatives. . . .'' Here, EPA failed to do so by not
analyzing SNCR for the Jim Bridger plant. In fact, EPA admits it did
not conduct a full BART analysis for SNCR for the Jim Bridger units:
``Because of our examination of the factors lead us to propose SCR as
reasonable for BART, we have eliminated SNCR for further
consideration.''
Response: We disagree with this comment. Our proposed rulemaking
notice clearly shows that we considered SNCR in our analysis (see Table
9 and Table 11 of the proposed rulemaking action).
Comment: One commenter stated that our proposed rule creates
unnecessary regulatory uncertainty by saying we propose to approve the
State's compliance deadlines for Jim Bridger Units 1 and 2, but then go
on to say we are seeking comment on a 2017 compliance deadline. They go
on to say that EPA must state unequivocally that they approve of the
State's existing compliance deadlines for Jim Bridger Units 1 and 2.
Response: We have responded to this comment in previous responses.
Comment: We received numerous general comments in favor of our
proposed approval of the State's SIP for the Jim Bridger Units 1-4.
Response: See responses to other comments above.
Comment: PacifiCorp supports EPA's proposed action to afford
``considerable deference'' to the Wyoming SIP with respect to what
controls are reasonable and when they should be implemented at Jim
Bridger Units 1 and 2, and that it would be unreasonable to require any
further retrofits at this source within five years of EPA's final
action. This is especially true given the extremely limited visibility
improvement that would be achieved if SCRs were installed within the
BART time period at Jim Bridger Units 1 and 2.
Further, PacifiCorp does not believe EPA, having reached the
conclusion that it would be unreasonable to require further retrofits
at Jim Bridger within five years, can reverse its decision simply by
inviting comment on an alternative proposal without further
consideration of the broader impacts of forcing more aggressive
controls within a five-year period.
Response: We have responded to this comment in previous responses.
Comment: We received numerous comments that an earlier compliance
deadline for the installation of SCR at Jim Bridger Units 1 and 2 would
be a significant burden and would be costly to PacifiCorp consumers.
Response: We have responded to this comment in other responses to
comments.
Comment: We agree with EPA that SCR represents BART for all four
Bridger units, but recommend a lower 30-day rolling average emission
limit (e.g. 0.06 lb/MMBtu) to reflect the true capabilities of SCR.
Response: We have addressed the control effectiveness of SCR above
in section V.C.3.
Comment: We received comments that BART for NOX
emissions at Jim Bridger Units 1-4 must be based on SCR and LNBs/SOFA,
which represents the best system of continuous emissions reduction and
that commenters agree with EPA's proposal to require this technology as
BART. Commenters went on to state that EPA must revise its BART-based
NOX emission limit for Units 1-4 from 0.07 lb/MMBtu to no
higher than 0.05 lb/MMBtu, which the selected technology can easily
achieve.
Response: We have addressed the control effectiveness of SCR above
in section V.C.3.
b. PM BART Determination
Comment: The fabric filter option discussed by Wyoming represents
PacifiCorp's estimate that application of a Compact Hybrid Particulate
Collector unit in addition to using flue gas conditioning with the
existing electrostatic precipitators can reduce emissions an additional
50% resulting in a PM10 emission rate of 0.015 lb/MMBtu.
Considering that EPA Region 9 proposed that the Desert Rock power plant
meet 0.010 lb/MMBtu, we believe that the Compact Hybrid Particulate
Collector option could achieve the same limit.
Response: See our response to a similar comment in section IV.C.6
of this rulemaking.
Comment: Neither Wyoming nor EPA completed the five-step BART
process for PM10 emissions. EPA asserted that: ``The State
did not provide visibility improvement modeling for fabric filters, but
EPA is proposing to conclude this is reasonable based on the high cost
effectiveness of fabric filters at each of the units. In addition, we
anticipate that the visibility improvement that would result from
lowering the limit from 0.03 lb/MMBtu to 0.015 lb/MMBtu would be
insignificant based on the State's analysis.''
We have several concerns with these conclusions: (1) EPA cannot
simply abort the five-step process once it has determined a technology
to be technically feasible; (2) EPA has overlooked the environmental
impact of SO3 emissions that may be released as a result of
PacifiCorp's FGC BART proposal; (3) Wyoming has underestimated the
effectiveness of the fabric filter option; and (4) Wyoming's fabric
filter costs are overestimated. For example, the cost estimates used by
Wyoming contained escalation, extra contingencies, and AFUDC, which are
not allowed by the CCM and have been rejected by EPA in other analyses.
The total for these improper costs exceeds $7 million per fabric
filter.
Even taken at face value, the cost/ton deemed ``high'' by EPA for
Units 2 and
[[Page 5190]]
3 are similar to or lower than cost/ton values accepted as reasonable
(for NOX) by states and by EPA in other analyses. EPA should
complete a proper five-step PM10 BART analysis by re-
evaluating the Compact Hybrid option on the basis of its ability to
achieve a lower limit (e.g., 0.010 lb/MMBtu), evaluating costs in
accordance with the BART Guidelines, comparing its cost-effectiveness
to other baghouse installations to properly assess the
``reasonableness'' of its cost, and determining the degree of
visibility improvement that would result from a lower PM10
limit.
Response: See our response to a similar comment in section IV.C.6
of this rulemaking.
3. Dave Johnston Units 3 and 4
a. NOX BART Determination
Comment: Wyoming has underestimated the ability of SCR to reduce
emissions. In estimating the annual cost-effectiveness of the
LNB+OFA+SCR option, Wyoming assumed 0.07 lb/MMBtu on an annual average
basis. Based on the 0.28 lb/MMBtu NOX emission rate
predicted for the LNB+OFA option, and the 0.23 lb/MMBtu annual emission
rates demonstrated by Johnston Unit 3 in 2011, outlet emissions at 0.07
lb/MMBtu represent only a 70%-75% SCR control efficiency as opposed to
the generally-accepted 90%. Based on the 0.15 lb/MMBtu NOX
emission rate predicted for the LNB+OFA option, outlet emissions at
0.07 lb/MMBtu represent only a 53% SCR control efficiency on Unit 4.
Wyoming has not provided any documentation or justification to support
the higher emission rates used in its analyses. In other recent BART
actions, EPA has determined that SCR can achieve 0.05 lb/MMBtu on an
annual basis. Such an underestimate at Johnston biases the cost-benefit
analysis against SCR and is inconsistent with other EPA analyses.
Response: The commenter has incorrectly assumed that a 90% control
efficiency can be achieved in all SCR applications regardless of the
input NOX emission rate or other parameters. In addition, we
note that the emission rate analyzed by Wyoming, 0.07 lb/MMBtu, was on
a 30-day rolling average basis, not an annual basis. Regardless, we
agree that SCR can in most cases achieve a performance rate of 0.05 lb/
MMBtu on an annual basis. (See section IV.C.4 of this rulemaking for
more information on the control effectiveness of SCR). We have revised
the SCR costs for Dave Johnston Units 3 and 4 accordingly.
Comment: Wyoming has overestimated the cost of SCR. A survey of
industry SCR cost data (conducted for the Utility Air Regulatory Group)
and EPA IPM estimates show that typical SCR costs for units the size of
the Johnston units would be $180-$300/kW. Wyoming's cost estimates for
SCR on Units 3 and 4 are $488 and $436/kW, respectively, which exceed
real-world industry costs ($50-$300/kW) and industry estimates, leading
us to believe that capital and annual costs are overestimated.
Response: See our response regarding the cost of SCR in section
IV.C.5 of this rulemaking.
Comment: Neither PacifiCorp nor Wyoming provided justification or
documentation for their cost estimates. We were not provided with any
vendor estimates or bids, and PacifiCorp and Wyoming did not use the
CCM. For example, the cost estimates used by Wyoming contained AFUDC,
which is not allowed by the CCM and has been rejected by EPA in other
analyses. The total for these improper costs exceeds $13 million.
Response: In order to address the cost analysis deficiencies noted
by the commenter, EPA has performed revised cost analyses for Dave
Johnston Units 3 and 4. In our revised cost analyses, we have followed
the structure of the CCM, though we have used the IPM cost models to
estimate direct capital costs and O&M costs.
Comment: Dave Johnston Unit 4 could very likely achieve a
NOX rate as low as 0.03 lb/MMBtu, which reflects 80%
NOX control across the SCR. A lower NOX emission
limit would increase the cost of the total system, but the cost
effectiveness of the system is actually improved because of the greater
NOX removal. The cost effectiveness of SCR plus LNBs/OFA at
Dave Johnston Unit 4 to meet a 0.03 lb/MMBtu NOX rate would
be $1,803/ton of NOX removed. EPA should require Dave
Johnston Unit 4 to install SCR plus LNBs/OFA to meet a NOX
rate of 0.03 lb/MMBtu or, at worst, no higher than 0.05 lb/MMBtu.
Response: We have addressed the control effectiveness of SCR above
in section V.C.3. Again, we have not selected LNBs with OFA and SCR for
Dave Johnston Unit 4 due to the high incremental cost effectiveness,
when considered within the context of the five factors.
Comment: EPA's use of undefined incremental cost effectiveness
versus incremental visibility benefit threshold is arbitrary in concept
and in its application. It is arbitrary in concept because EPA has not
provided any reasoned basis for its approach let alone disclosed the
threshold it applies. It is arbitrary in application, because in the
case of Dave Johnston Unit 4, the visibility benefits of SCR do justify
its cost, as EPA has found for other units.
Response: We disagree. We have made our determination based on a
weighing of the five factors. One of the factors to be considered is
cost-effectiveness, both average and incremental. For Dave Johnston
Unit 4, we have determined that the incremental costs, when considered
with the other BART factors, does not make the selection of SCR
reasonable.
Comment: The EPA failed to support its conclusion that SNCR, rather
than SCR, is BART for Dave Johnston Unit 4. The EPA's sole basis for
rejecting SCR as BART for Dave Johnston Unit 4 was the incremental cost
effectiveness of the control, which EPA estimated to be $11,951, but
the EPA has not supported this line-drawing with reference to the
statutory BART factors or purpose of the regional haze program. Without
providing objective standards or rationale to support its
determination, the EPA's judgment that the incremental cost
effectiveness of SCR on Dave Johnston Unit 4 is too high appears
arbitrary.
The EPA's analysis of incremental cost effectiveness for Dave
Johnston Unit 4 also cannot drive the Agency's BART determination
because EPA overestimated the cost of SCR for Unit 4. The EPA found the
average cost effectiveness of SCR to be reasonable for the unit, but
the costs are even lower than the EPA assumed because the EPA used
unjustified ``retrofit factors,'' interest rate, and auxiliary power
costs.
Response: As stated in our response above, we have made our
determination based on a weighing of the five factors. One of the
factors to be considered is cost-effectiveness, both average and
incremental. For Dave Johnston Unit 4, we have determined that the
incremental costs, when considered with the other BART factors, does
not make the selection of SCR reasonable.
In addition, we have revised the costs of SCR for Dave Johnston
Unit 3 in support of our final rulemaking. The revised costs are no
longer based on a retrofit factor, but instead are based on a budgetary
price from an equipment vendor submitted by PacifiCorp during the
comment period. We feel that use of the vendor data for SCR provides a
more accurate capital cost than when using a retrofit factor. For
reasons described in separate responses, we continue to find that use
of the social discount rate of 7% is appropriate for regulatory
applications such as BART determinations. We have corrected the
[[Page 5191]]
auxiliary power costs to reflect busbar, and not market price of power;
however this has a small affect on overall costs. Our cost methodology
and assumptions are described in detail in the cost report that can be
found in the docket.
Comment: SCR on Dave Johnston Unit 4 would likely result in even
greater NOX emission reductions than EPA assumed, further
undermining the Agency's exclusive reliance on incremental cost
effectiveness to reject SCR as BART. An emission rate lower than 0.05
lb/MMBtu on a 30-day average is achievable for Dave Johnston Unit 4
because this unit operates combustion controls that independently
control NOX emissions to a 30-day average of 0.13 lb/MMBtu
(compared with the 0.22 lb/MMBtu NOX-emission rate achieved
at Unit 3). At this emission level, SCR would only need to remove 66.4
percent of NOX emissions to achieve an emission rate of 0.05
lb/MMBtu, while SCR is capable of achieving NOX reductions
of 90 percent. The EPA should have evaluated the cost-effectiveness of
SCR on Dave Johnston Unit 4 based on even greater NOX
emissions reductions that are readily achievable.
Response: We disagree. First, the commenter has incorrectly assumed
that a 90 percent reduction in NOX is achievable with SCR
regardless of inlet rate or other parameters. In most cases, SCRs are
designed for a performance emission rate, such as in lb/MMBtu, and not
the anticipated percent reduction. In the case of Dave Johnston Unit 4,
the low emissions currently being achieved with combustion controls are
not an indication that the SCR would achieve greater reductions than
estimated by EPA. In fact the exact opposite is true: the lower the
inlet rate to the SCR, the less NOX that will be removed as
there are simply fewer tons to remove. Finally, we note that we have
revised our cost calculations to support the determinations in today's
final rule. In our revised analysis, we calculate that the incremental
cost effectiveness of SCR is $13,312/ton, as opposed to $11,951/ton.
This reinforces our conclusion that SCR is not appropriate for Dave
Johnston Unit 4. Our cost methodology and assumptions are described in
detail in the cost report that can be found in the docket.
b. Alternative Control Technology Proposal
Comment: Dave Johnston Unit 3 was retrofitted with LNB and
separated OFA in the spring of 2010, and Unit 4 was retrofitted with
the same technology in early 2009. EPA recognizes that Unit 3 has a
current annual NOX emission rate of about 0.22 lb/MMBtu, and
Unit 4 has a rate of about 0.14 lb/MMBtu. The potential additional
NOX controls that may be added to these units include SNCR
and SCR. Should an alternate control technology be considered by EPA
for Dave Johnston Unit 3, SNCR is preferable to SCR for Dave Johnston
Unit 3 when considering all currently available information and the
current emissions performance of the unit.
Even though the cost of SNCR is unacceptably high for Unit 3
(approximately $5,500 per ton NOX removed), it is still far
less than the tremendously expensive cost of SCR ($15,769 per ton
NOX removed for Unit 3), particularly when taking into
account the incrementally small modeled visibility improvement between
the technologies.
Response: As described in section III.B of this document, we have
re-evaluated the cost of compliance for Dave Johnston unit 3 to reflect
a shorter remaining useful life (9 years as opposed to 20 years)
because PacifiCorp has volunteered to install SNCR and retire the unit
in 2027 in lieu of installing SCR under our proposed rule. As we
explain there, our revised BART analysis shows that neither SNCR nor
SCR is reasonable over this shorter remaining useful life. However, our
analysis continues to support a conclusion that SCR is warranted if the
costs of compliance are calculated over a 20-year remaining useful
life. Therefore, we have also included an to give PacifiCorp the option
to meet a 0.07 lb/MMBtu emission limit (assumes installation of SCR)
within five years of today's action instead of shutting down the unit.
Comment: With respect to Dave Johnston Unit 4, EPA has concluded
that SNCR is BART for that unit. As such, PacifiCorp has only provided
updated SNCR information for Unit 4, considering all currently
available information and the current emissions performance of the
unit. The cost of SNCR for Unit 4 is unacceptably high and not cost
effective (approximately $12,000 per ton NOX removed). The
alternate control technology for Dave Johnston Unit 4 would be LNB/OFA,
as is currently installed today.
Response: We disagree with the cost effectiveness estimates
provided by the commenter. Nonetheless, as described above, in
consideration of comments received during the public comment period, we
have re-evaluated our cost of compliance estimates for Dave Johnston
Unit 4. Our revised costs, when taken along with the remaining BART
factors, no longer show that SNCR is warranted for Dave Johnston Unit
4. Therefore, we agree that BART for Dave Johnston Unit 4 is the
currently installed combustion controls (LNB/OFA).
4. Naughton Units 1-3
a. NOX BART Determination
Comment: The EPA proposes to accept Wyoming's SIP proposal to
identify SCR as BART on Naughton Unit 3 and to require SCR to reduce
NOX emissions from Naughton Unit 1 and 2. The EPA properly
recognized that the costs of SCR on Naughton Units 1-3 are reasonable.
However, the EPA's estimate of costs is significantly inflated, and the
true costs are even lower than EPA found because the EPA used
unjustified ``retrofit factors,'' interest rate, and auxiliary power
costs. The recalculation of costs using what the commenter believes are
corrected inputs resulted in significantly lower SCR costs of $1,501 to
$1,788/ton at all three Naughton units. On this basis, SCR is very cost
effective on these units and at the low end of the cost threshold when
scanning NOX reduction costs elsewhere. SCR also is
justified by the visibility benefits it would afford, which
additionally supports EPA's findings that SCR reflects BART for
Naughton Units 1-3.
Response: EPA believes that the retrofit factors used in cost
estimates were reasonable and has described in detail the reasoning for
the retrofit factors in other responses. EPA also discussed the
reasoning for the assumed interest rate in responses to other comments.
EPA has revised its cost estimates and has made changes where EPA
believed that input from commenters justified changes.
Comment: EPA should evaluate the feasibility and cost-effectiveness
of further NOX reductions that could be achieved by a more-
efficient SCR. EPA is proposing that the FIP NOX BART
emission limit for Naughton Unit 1, Unit 2, and Unit 3 is 0.07 lb/MMBtu
(30-day rolling average). While we are generally pleased with EPA's
proposal, we note that EPA's analysis is based on only 76%
NOX control by the SCRs on Units 1 and 2, and 85% control by
the SCR on Unit 3. This still results in Unit 2 contributing 0.5
deciviews and Unit 3 contributing 0.9 deciviews to visibility
impairment at Badlands National Park.
Response: We have addressed the control effectiveness of SCR above
in section V.C.3 above.
Comment: A NOX limit of 0.07 lb/MMBtu on a rolling 30-
boiler operating day basis would only require Naughton Units 1 and 2 to
achieve 71 percent NOX removal and Naughton Unit 3 to
achieve 80 percent NOX removal across the SCR system based
on an evaluation of
[[Page 5192]]
available CAMD emissions data. A 0.05 lb/MMBtu NOX emission
limit applicable on a rolling 30-boiler operating day average basis
would require 79 percent NOX removal across the SCR at
Naughton Units 1 and 2 and 85.7 percent NOX removal at
Naughton Unit 3, which is achievable.
Response: We have addressed the control effectiveness of SCR above
in section V.C.3 above.
Comment: We received comments that Wyoming has underestimated the
ability of SCR to reduce emissions. Commenters stated that in
estimating the annual cost-effectiveness of the LNB+OFA+SCR option,
Wyoming assumed 0.07 lb/MMBtu on an annual average basis. Based on the
0.026-0.37 lb/MMBtu NOX emission rate predicted for the
combustion control option, outlet emissions at 0.07 lb/MMBtu represent
only 73%-81% SCR control efficiency as opposed to the generally
accepted 90%. Commenters went on to point out that in other recent BART
actions, EPA has determined that SCR can achieve 0.05 lb/MMBtu on an
annual basis.
Response: The commenters have incorrectly assumed that a 90%
control efficiency can be achieved in all SCR applications regardless
of the input NOX emission rate or other parameters. In
addition, we note that the emission rate analyzed by Wyoming, 0.07 lb/
MMBtu, was on a 30-day rolling average basis, not an annual basis.
Regardless, we agree that SCR can in most cases achieve a performance
rate of 0.05 lb/MMBtu on an annual basis. (See section IV.C.4 of this
rulemaking for more information regarding the control effectiveness of
SCR). We have revised the SCR costs for the Naughton units accordingly.
Comment: A survey of industry SCR cost data (conducted for the
Utility Air Regulatory Group) and IPM estimates show that typical SCR
costs for units the size of the Naughton units would be $280-$330/kW.
Wyoming's cost estimates for SCR are $412-$531/kW, which exceed real
world industry costs ($50-$300/kW) and industry estimates, leading us
to believe that capital and annual costs are overestimated.
Response: See our response regarding the cost of SCR in the section
V.B.2 of this rulemaking.
Comment: Neither PacifiCorp nor Wyoming provided justification or
documentation for their cost estimates. We were not provided with any
vendor estimates or bids, and PacifiCorp and Wyoming did not use the
CCM. For example, the cost estimates used by Wyoming contained AFUDC
which is not allowed by the CCM and has been rejected by EPA in other
analyses. The total for these improper costs exceeds $17 million.
Response: In our revised SCR cost analysis for the Naughton units,
we followed the framework of the CCM (although we derived direct
capital costs and O&M costs using the more recent approach found in the
IPM cost models). For example, we did not allow for owner's costs and
AFUDC. Therefore, we have addressed the concerns raised by the
commenter.
b. Alternative Control Technology Proposal
Comment: EPA requested additional information on the conversion of
Naughton Unit 3 from a coal fired unit to a natural gas fired unit. 78
FR 34760. EPA must evaluate PacifiCorp's fuel conversion in accordance
with Appendix Y as a ``better-than-BART'' alternative and not as a BART
control technology option because EPA had made clear in its BART
Guidance that ``it is not [EPA's] intent to direct States to switch
fuel forms, e.g. from coal to gas,'' as part of the BART analysis. 70
FR 39104, 39164. PacifiCorp voluntarily submitted its permit
application to convert Naughton Unit 3 to natural gas, the State issued
a federally enforceable permit requiring such conversion. Compliance
with the permit is therefore not voluntary.
The permitted NOX performance level of Naughton Unit 3
after conversion to natural gas is 0.08 lb/MMBtu based on a 30-day
rolling average and not 0.10 lb/MMBtu based on a 30-day rolling average
as stated in PacifiCorp's permit application. Additionally, the
permitted NOX mass emission rate is 250 lb/hr based on a 30-
day rolling average, which is protective of visibility and lower than
the BART-determined NOX rate of 259 lb/hr based on the same
averaging period. Finally, annual NOX emissions will be
reduced from the BART level of 1,134 tons to 519 tons.
Response: We tentatively agree that the conversion of Naughton Unit
3 to natural gas is better-than-BART for that individual unit, however,
the State has not provided a SIP for EPA's action on this option. EPA
does not have the authority to approve the conversion without a SIP
submittal, and is, therefore, approving the State's BART determination
for SCR at Naughton Unit 3 without making a final determination on
whether the conversion is better-than-BART for that unit. In lieu of
our approval of the State's BART determination for Naughton Unit 3, EPA
is committed to take expedited action on a future SIP revision for
Naughton Unit 3 reflecting the conversion if the State submits such a
revision. That action would constitute our final determination on the
conversion.
Comment: Rather than install the control equipment required by the
Wyoming SIP, PacifiCorp will convert the unit to fire natural gas by
the end of 2017. A construction permit allowing the conversion has been
issued by Wyoming, and PacifiCorp is moving ahead with a request for
Wyoming to modify the Wyoming SIP to accommodate this change. The
construction permit issued by Wyoming requires Naughton Unit 3 to cease
burning coal by December 31, 2017 and to be retrofitted to natural gas
as its fuel source by June 30, 2018. PacifiCorp requests that EPA's
final FIP include this compliance alternative for Naughton Unit 3.
Response: See our response above.
Comment: The Conservation Organizations support the Naughton Unit 3
conversion to natural gas within the first five-year regional haze
planning period as a better-than-BART alternative to installation of
SCR on Unit 3. We recognize that a gas conversion will virtually
eliminate SO2 emissions as well as greatly reduce
NOX and PM emissions resulting in significant visibility
benefits.
However, to the extent that EPA is considering whether the Naughton
Unit 3 is better than BART as proposed for all three Naughton Units
(i.e., whether the conversion may be approved ``instead of . . . BART
as proposed'' for Naughton Units 1 and 2, 78 FR 34783), the
Conservation Organizations object. The Conservation Organizations
conducted visibility modeling to determine whether PacifiCorp's
proposed natural gas conversion at Unit 3 (with LNB and OFA at Units 1
and 2) would result in greater visibility improvement than would EPA's
re-proposed BART alternative of SCR at all three Naughton Units. The
analysis shows that EPA's re-proposed SCR BART determination
consistently results in greater visibility improvement over the gas
conversion scenario. Thus, the conversion of Naughton Unit 3 to gas
with LNB/OFA on Units 1 and 2 does not satisfy the ``better-than-BART''
standards of the regional haze regulations. Whether or not PacifiCorp
converts Naughton Unit 3 to natural gas, EPA must require the
installation of SCR to meet an emission limit of 0.05 lb/MMBtu to
satisfy BART for Naughton Units 1 and 2.
Response: We acknowledge the support for a natural gas conversion
as a better-than-BART alternative for Naughton Unit 3. If the State
submits a SIP revision reflecting the conversion,
[[Page 5193]]
we will take expedited action on it. As discussed elsewhere, we are
approving the State's SIP submittal for all Naughton Units based on our
consideration of the five BART factors. The remainder of the comment is
therefore not relevant.
5. Wyodak
Comment: Wyoming has underestimated the ability of SCR to reduce
emissions. In estimating the annual cost-effectiveness of the
LNB+OFA+SCR option, Wyoming estimated 0.07 lb/MMBtu on an annual
average basis. Based on the 0.18 lb/MMBtu NOX emission rate
predicted for the LNB+OFA option, outlet emissions at 0.07 lb/MMBtu
represent only a 61% SCR control efficiency as opposed to the
generally-accepted 90%. Wyoming has not provided any documentation or
justification to support the higher emission rates used in its
analyses. In other recent BART actions, EPA has determined that SCR can
achieve 0.05 lb/MMBtu on an annual basis. Such an underestimate at
Wyodak biases the cost-benefit analysis against SCR and is inconsistent
with other EPA analyses.
Response: The commenter has incorrectly assumed that a 90% control
efficiency can be achieved in all SCR applications regardless of the
input NOX emission rate or other parameters. In addition, we
note that the emission rate analyzed by Wyoming, 0.07 lb/MMBtu, was on
a 30-day rolling average basis, not an annual basis. Regardless, we
agree that SCR can in most cases achieve a performance rate of 0.05 lb/
MMBtu on an annual basis. (See section IV.C.4 of this rulemaking for
more information regarding the control effectiveness of SCR). We have
revised the SCR costs for Wyodak accordingly.
Comment: A survey of industry SCR cost data and EPA IPM estimates
show that typical SCR costs for units the size of Wyodak would be $180-
$280/kW. Wyoming's cost estimates for SCR are $474/kW, which exceed
real-world industry costs ($50-$300/kW) and industry estimates, leading
us to believe that capital and annual costs are overestimated.
Response: See our response regarding the cost of SCR in section
IV.C.5 of this rulemaking.
Comment: Neither PacifiCorp nor Wyoming provided justification or
documentation for their cost estimates. We were not provided with any
vendor estimates or bids, and PacifiCorp and Wyoming did not use the
CCM. For example, the cost estimates used by Wyoming contained AFUDC,
which is not allowed by the CCM and has been rejected by EPA in other
analyses. The total for these improper costs exceeds $8 million.
Response: In our revised SCR cost analysis for Wyodak, we followed
the framework of the CCM (although we derived direct capital costs and
O&M costs using the more recent approach found in the IPM cost models).
For example, we did not allow for owner's costs and AFUDC. Therefore,
we have addressed the concerns raised by the commenter.
Comment: The addition of SCR at Wyodak should be required because
it is consistent with the other BART determinations EPA has made. EPA
is proposing that the FIP NOX BART is new LNBs with OFA plus
SNCR at an emission limit of 0.17 lb/MMBtu. EPA proposes to eliminate
new LNBs with advanced OFA plus SCR. The cumulative cost effectiveness
of adding SCR to Wyodak is equivalent to EPA's accepted values at
Laramie River Unit 2. Based upon cost and visibility improvement, we
believe that SCR is BART for Wyodak. As EPA stated in its notice,
``cost-effectiveness and visibility improvement are within the range of
other EPA FIP actions.'' Even though cumulative visibility improvement
is relatively low, so are SCR costs.
A NOX limit of 0.07 lb/MMBtu on a rolling 30-boiler
operating day basis would only require Wyodak to achieve 67 percent
NOX removal across the SCR system based on an evaluation of
available CAMD emissions data. A 0.05 lb/MMBtu NOX emission
limit applicable on a rolling 30-boiler operating day average basis
would require 76 percent NOX removal across the SCR, which
the commenter believes is achievable.
Response: As a result of other comments we have received, we are
finalizing a NOX BART determination of new LNBs with OFA
plus SCR for Wyodak. We agree with the portion of this comment that
states this is consistent with other EPA BART determinations. We
disagree with the remainder of the comment. As we have discussed in
other responses, we are not required, nor have we chosen to, use the $/
deciview metric, let alone the same on a cumulative basis, when
assessing BART.
We have addressed the control effectiveness of SCR above in section
V.C.3.
Comment: For Wyodak, EPA is proposing that the FIP NOX
BART is new LNBs with OFA plus SNCR at an emission limit of 0.17 lb/
MMBtu. EPA proposes to eliminate new LNBs with advanced OFA plus SCR
because: ``Although the cost-effectiveness and visibility improvement
are within the range of other EPA FIP actions, we find that the
cumulative visibility improvement of 1.16 deciviews for new LNBs with
OFA plus SCR is low compared to the cumulative visibility benefits that
will be achieved by requiring SCR at Dave Johnston Unit 3 (2.92
deciview), Laramie River Unit 1 (2.12 deciview), Laramie River Unit 2
(1.97 deciview), Laramie River Unit 3 (2.29 deciview), Naughton Unit 1
(3.54 deciview), and Naughton Unit 2 (4.18 deciview).''
Because the cumulative visibility improvement from EPA's proposed
control strategy is barely half of the visibility improvement that EPA
rejected as ``low,'' then visibility improvement cannot be the only
factor relied upon by EPA in making its BART determination. We can only
conclude that EPA is somehow relating visibility improvement to another
factor. For example, after correcting for the unsupported 1.3 retrofit
factor at this relatively simple, single-EGU facility, the cost-
effectiveness of adding SCR is $16 million/deciview at Wind Cave
National Park, and $10 million/cumulative deciview. By comparison,
based upon EPA estimates, addition of SCR to Laramie River Unit 3
results in $28 million/deciview at the most-impacted Class I area, and
addition of SCR to Laramie River Unit 2 yields $10 million/cumulative
deciview. The cumulative cost effectiveness of adding SCR to Wyodak is
equivalent to EPA's accepted values at Laramie River Unit 2.
Response: We disagree with the suggested use of the $/deciview
metric. As we have discussed in other responses, we are not required,
nor have we chosen to, use the $/deciview metric, let alone the same on
a cumulative basis, when assessing BART. Even if we had, the
commenter's position is predicated on their assertion that EPA
inappropriately applied a retrofit factor for SCR at Wyodak. As we have
discussed in other responses, we disagree that it was inappropriate to
apply a retrofit factor of 1.3. However, as explained below, we agree
that we should not have relied on the basis stated in our proposal to
reject SCR. For Wyodak, we find that the visibility improvements at two
Class I areas, when weighed with the other BART factors, makes SCR
reasonable as BART.
Comment: Based upon cost and visibility improvement, we believe
that SCR is BART for Wyodak. Under the EPA proposal, Wyodak would still
contribute over 0.7 deciview impairment at Wind Cave National Park (and
exceed 0.5 deciviews at Badlands National Park). With the addition of
SCR, impairment would drop to less
[[Page 5194]]
than 0.5 deciviews at all Class I areas. As EPA stated in its proposal,
``cost-effectiveness and visibility improvement are within the range of
other EPA FIP actions.'' Even though cumulative visibility improvement
is relatively low, so are SCR costs. Addition of SCR at Wyodak should
be required because it is consistent with the other BART determinations
EPA has made here.
Response: After further consideration, we agree that it was
inappropriate for EPA to reject SCR as BART for Wyodak based on the
rationale that Wyodak's emissions affect fewer Class I areas than
Wyoming's other BART-eligible sources. Where consideration of the five
factors demonstrates that a control is reasonable in light of the
visibility improvement that will occur at the most impacted Class I
area, as was the case here for Wyodak and Wind Cave, the fact that
additional Class I areas will also experience visibility improvement
can only bolster the case for that control's selection, not undermine
it. In other words, the fact that Wyodak's emissions affect two Class I
areas instead of six or seven is irrelevant if the improvement at just
one Class I area is sufficient to warrant a control's selection as
BART. Consequently, we have reassessed the five factors for Wyodak and
now conclude, even after taking into account our revised cost estimates
and visibility modeling, that LNB/OFA + SCR is NOX BART for
Wyodak Unit 1.
Comment: SCR with an emission limit of 0.05 lb/MMBtu should be
required as NOX BART for Wyodak, rather than an SNCR-based
limit of 0.17 lb/MMBtu as EPA proposes. EPA properly recognized that
the cost-effectiveness and incremental cost-effectiveness of SCR to
reduce Wyodak's NOX emissions are reasonable, but
nonetheless proposed to reject SCR on the basis of purportedly
insufficient cumulative visibility benefits. EPA's proposed
determination is improper, because EPA has failed to justify why
incremental visibility benefits over the large number of Class I Areas
impacted by Wyodak's NOX emissions should not be required to
achieve reasonable progress toward the national visibility goal,
particularly in light of the fact that none of the Wyoming Class I
areas affected by Wyodak's NOX emissions are projected to
achieve the Uniform Rate of Progress (URP) in 2018. Moreover, while EPA
evaluated the impacts of Wyodak's NOX emissions only at Wind
Cave and Badlands National Parks, our supplemental modeling shows that
SCR to control Wyodak's NOX emissions will nearly eliminate
the plant's perceptible visibility impacts at 18 Class I areas. EPA's
visibility justification for rejecting SCR as BART was improper because
Congress has directed EPA to require BART ``for the purpose of
eliminating or reducing any [visibility] impairment'' caused by the
source. 42 U.S.C. 7491(b)(2)(A). Installing SCR at Wyodak would resolve
this impairment.
Response: See our response to the previous comment. While we do not
agree with the commenter's assertion that Wyodak's emissions have
perceptible visibility impacts at 18 Class I areas or that the URP is
relevant for purposes of a BART determination, we do agree that our
decision to eliminate SCR based on cumulative visibility improvement
was improper.
Comment: EPA properly recognized that the cost-effectiveness and
incremental cost-effectiveness of SCR to reduce Wyodak's NOX
emissions are reasonable, but nonetheless proposed to reject SCR on the
basis of purportedly insufficient cumulative visibility benefits. EPA's
estimate of costs is significantly inflated, and the true costs are
lower than EPA found because the EPA used unjustified ``retrofit
factors,'' interest rate, and auxiliary power costs. On these bases,
the EPA should require SCR at Wyodak as BART.
Response: See our previous two responses.
6. Trona Mines
a. FMC Westvaco and General Chemical Green River
Comment: EPA should reconsider whether SCR plus combustion controls
is BART for the FMC Westvaco Units NS-1A and NS-1B. At $3,493/ton, as
presented by EPA, SCR may be a cost-effective option. Furthermore, EPA
should evaluate whether the cost of SCR for FMC Westvaco Units NS-1A
and NS-1B were calculated correctly.
Response: Although EPA has not re-evaluated the cost of SCR at the
FMC Westvaco Units, we note the relatively low visibility improvement
from SCR for each unit (0.24 deciviews). Because of the low visibility
improvement from SCR, we do not find that a reconsideration of costs
would necessarily have led EPA or the State to a different conclusion
regarding the selection of SCR.
Comment: At a minimum, EPA must require SNCR and LNB + SOFA as BART
for NOX at the Westvaco plant. EPA determined that this
enhanced technology could achieve a 0.21 lb/MMBtu NOX
emissions rate. This would result in a 70% reduction in NOX
emissions from current levels, rather than just a 50% reduction that
would result from the 0.35 lb/MMBtu emission rate currently proposed.
Requiring SNCR would lead to NOX emissions reductions of
1,903 tpy. SNCR in addition to LNB+SOFA is highly cost effective at
$673/ton. This is well within the range of BART costs that EPA has
found reasonable for SNCR at other facilities, including facilities in
Wyoming. For example, EPA proposes to reject Wyoming's NOX
BART proposal for Wyodak Unit 1, and instead to require LNB+OFA+SNCR as
BART, finding the technology cost effective at $958/ton, a higher cost
than the same technology at the Westvaco boilers.
Response: We disagree with this comment. First, SNCR at each of the
units would achieve a 0.19 deciview improvement, with an incremental
visibility improvement of 0.06 deciviews. The cost effectiveness for
LNBs compared to LNBs with SNCR is more than double ($304/ton compared
to $673/ton). Based on this information, we find it reasonable for the
State not to determine SNCR is BART for these units based on a
consideration of the five factors, including the visibility
improvement.
Comment: Requiring SNCR at the FMC Westvaco plant would improve
visibility at affected Class I areas. EPA states that Wyoming's
visibility modeling for this facility demonstrated a 0.19 deciview
improvement at the Bridger Wilderness Area from the installation of
SNCR on each boiler. In fact, Wyoming's modeling demonstrated a 0.198
deciview visibility improvement for the maximum 98th percentile impact
at Bridger Wilderness Area. The combined visibility improvement due to
SNCR at both Westvaco boilers is nearly 0.4 deciviews at the Bridger
Wilderness Area alone. EPA found it appropriate to consider the
combined visibility impact of pollution controls on multiple units at a
single facility in determining that BART is SNCR for Units 1 and 2 of
the Colstrip facility in Montana and should likewise consider the
combined visibility impact of SNCR on the two Westvaco boilers.
Response: We have addressed a similar comment above in section V.B
of this rulemaking. We recognize that there may be some efficiencies in
installing SNCR on two units (e.g., a common reagent supply system),
but expect that this would provide only a modest reduction in annual
costs. We do not find that the combined benefit for the two FMC
Westvaco boilers, 0.4 deciviews, is a basis for requiring SNCR.
Comment: Wyoming's modeling also showed that SNCR could virtually
eliminate the visibility impairment at the Bridger Wilderness Area
caused by
[[Page 5195]]
the FMC Westvaco Units NS-1A and NS-1B, reducing the number of days of
noticeable visibility impairment caused by each boiler from eleven to
just one. Visibility in the Bridger Wilderness Area is presently
diminished by 4.6 deciviews from natural conditions and, under EPA's
proposed action, it will not achieve natural conditions until 2165. A
0.4 deciview visibility improvement at the Bridger Wilderness Area is
particularly significant in light of new sources of haze-causing
pollution from the oil and gas industry that will affect this area.
NOX emissions from Wyoming oil and gas development are
expected to more than double in the current regional haze planning
period, from 14,725 tpy in 2002 to 34,142 tpy in 2018, yet EPA does not
propose any NOX emissions reductions from this sector.
Accordingly, it is imperative for Wyoming and EPA to reduce
NOX emissions from every other source to the greatest extent
possible, including by requiring SNCR to be installed at the FMC
Westvaco Units NS-1A and NS-1B.
Response: We disagree with this comment. BART is a source-by-source
analysis taking into consideration the five factors. The BART
Guidelines and RHR do not require states or EPA to take into
consideration the state being able to achieve the URP for a Class I
area in its determination of BART for individual BART units.\236\
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\236\ In determining the measures necessary to make reasonable
progress and in selecting RPGs for mandatory Class I areas within
Wyoming, the State took into account the following four factors into
consideration: Costs of compliance; time necessary for compliance;
energy and non-air quality environmental impacts of compliance; and
remaining useful life of any potentially affected sources. CAA
section 169A(g)(1) and 40 CFR 51.308(d)(1)(i)(A). 40 CFR
51.308(d)(1)(ii) allows for a slower rate of improvement in
visibility than the URP, as long as it is demonstrated that based on
these four factors, it is not reasonable to achieve the URP and that
the selected RPG is reasonable. CAA section 169A(g)(1) and 40 CFR
51.308(d)(1)(i)(A).
---------------------------------------------------------------------------
Comment: Wyoming's modeling, upon which EPA relied, excluded all
Class I areas beyond 300 km from the Westvaco facility. However, there
is no demonstration that Class I areas further afield are not impacted
by the Westvaco facility. As a comparison, EPA recently approved the
South Dakota regional haze SIP which includes BART limits for the Big
Stone facility, for which the nearest Class I area is over 400 km away.
Response: We explained in response to another comment the reasons
why we did not evaluate visibility impairment at Class I areas at
distances greater than 300 km. Regarding the South Dakota regional haze
SIP, there are no Class I areas within 300 km of the Big Stone
Facility. Therefore, it was reasonable for the state to evaluate
visibility impacts at the nearest Class I area even though the distance
was greater than 300 km. We note that the BART rule provides some
flexibility to the states in the approach used to evaluate visibility
impairment. The fact that South Dakota chose to evaluate visibility
impacts at a distance greater than 300 km does not impose a similar
requirement on other states.
Comment: Considering just the two Class I areas modeled, the
installation and operation of SNCR would result in a cumulative maximum
98th percentile visibility improvement of 0.304 deciviews from each
unit, or 0.608 from both units combined. This cumulative visibility
improvement at two Class I areas is significant and amply justifies
SNCR, at a minimum, as BART.
Response: In the proposed rule, we did focus on the visibility
benefits at the most impacted Class I area. We considered the
visibility benefits at the other Class I areas, but did not consider
the benefits sufficient to warrant a change in our determination as to
the appropriate level of control.
Comment: Although the cost effectiveness and visibility
improvements due to SNCR and LNB+SOFA standing alone justify a
determination that this combination of technologies is BART, EPA
apparently agreed with Wyoming that the incremental costs of requiring
SNCR were not justified by the resulting visibility improvement. EPA's
consideration of incremental cost effectiveness and visibility benefit
is arbitrary given the lack of any objective criteria and in any event,
must not be viewed in a vacuum.
Response: We disagree with this comment. As stated above, we find
it reasonable, based on a consideration of the five factors, including
the low visibility improvement, for the State to find that SNCR and
LNBs was not reasonable for BART.
Comment: Although the State and EPA determined that addition of
combustion controls is BART for the three BART boilers at these two
facilities, it is unclear how they arrived at these conclusions. The
visibility improvement from EPA's proposed controls for the trona
plants are less than the visibility improvement that EPA rejected as
``low'' in the EGU BART analyses, so it appears that EPA is using
different criteria for these facilities or relating visibility
improvement to another factor, which we assume to be some combination
of cost and visibility improvement. (Otherwise, one would always choose
the control strategy with the greatest visibility improvement.)
However, it appears that EPA did not evaluate the cost analyses
presented by the companies and the State, so we are concerned that the
cost analyses for these two trona plants may suffer for the same
problems that we pointed out to EPA before regarding the EGUs. For
example, although Boiler D at Green River is the same size as the FMC
boilers: (1) FMC evaluated addition of new combustion controls in
combination with SNCR or SCR, Green River did not. (2) The capital cost
of adding SNCR at Green River Boiler D is more than four times FMC. (3)
EPA presented cost-effectiveness of SNCR as $3,176/ton at Green River
Boiler D. The actual cost-effectiveness, based on EPA's annual cost and
emission reduction, is $1,637/ton. (4) FMC assumed that SCR could
reduce NOX by 31% to 0.10 lb/MMBtu, Green River assumed 80%
NOX reduction to 0.14 lb/MMBtu. (EPA typically assumes that
SCR can achieve 0.05 lb//MMBtu on an annual basis.) (5) SCR capital
cost is $43 million at FMC, $19 million for Green River Boiler D. (6)
EPA presented cost-effectiveness of SCR as $3,510/ton at Green River
Boiler D. The actual cost-effectiveness, based on EPA's annual cost and
emission reduction, is $2,339/ton.
It is apparent that EPA must have been considering the costs of
controls, but, in view of the substantial discrepancies noted above,
those costs are questionable. In view of these discrepancies, we
question how EPA rejected the more-effective control technologies (SNCR
and SCR) that produce greater visibility improvements for the proposed
controls.
Response: We disagree with this comment. Even if the cost of SNCR
and SCR were reduced, we find that the visibility improvement (Boiler
C--0.08 deciviews for SNCR and 0.14 deciviews for SCR; Boiler D--0.12
deciviews for SNCR and 0.17 deciviews for SCR) would not warrant the
selection of post-combustion controls for BART.
b. FMC Granger Trona Mine
Comment: EPA proposes to approve Wyoming's determination that the
FMC Granger trona mine, while BART-eligible, is not subject-to-BART.
The basis for EPA's proposed approval is that the visibility impact of
this facility at the Bridger Wilderness Class I area would be 0.39
deciviews, and EPA proposes to ``agree with Wyoming that 0.5 deciviews
is a reasonable threshold for determining whether its BART-eligible
sources are subject-to-BART.'' EPA should reconsider its determination
that the Granger facility is not subject-to-BART. In making the
[[Page 5196]]
subject-to-BART determination at least three considerations must be
incorporated pursuant to EPA's BART guidelines: Whether the source
causes or contributes to visibility impairment in a Class I area, the
number of emissions sources affecting a Class I area, and the magnitude
of the individual source impacts. Wyoming determined that the Granger
plant was not subject-to-BART because its visibility impairment level
at the Bridger Wilderness was predicted to be 0.39 deciviews--below the
0.5 deciview threshold. Wyoming's determination was flawed however
because it apparently did not consider the other factors essential to a
subject-to-BART determination, i.e., the number of emissions sources
affecting the Class I area and the magnitude of the individual sources'
impacts.
There are a large number of pollution sources affecting visibility
in the Bridger Wilderness Area, including significant impacts from
thousands of operating oil and gas wells that are not BART-eligible.
This fact highlights the need for maximum feasible emissions from each
source contributing to impairment at the Bridger Wilderness Area,
particularly sources like the FMC Granger trona mine, which is eligible
for BART controls.
Response: We disagree with this comment. Wyoming used a
contribution threshold of 0.5 deciviews for determining which sources
are subject-to-BART. By using a contribution threshold of 0.5
deciviews, Wyoming exempted seven of the fourteen BART-eligible sources
in the State from further review under the BART requirements. Based on
the modeling results, the State determined that P4 Production, FMC
Granger, and OCI Wyoming had an impact of .07 deciviews, 0.39 deciview,
and 0.07 deciview, respectively, at Bridger Wilderness. Black Hills
Neil Simpson 1, Sinclair Casper Refinery, and Sinclair--Sinclair
Refinery have an impact of 0.27 deciview, 0.06 deciview, and 0.12
deciview, respectively, at Wind Cave. Dyno-Nobel had an impact of 0.22
deciview at Rocky Mountain National Park. These sources' modeled
visibility impacts fell below the State's threshold of 0.5 deciview and
were determined not to be subject-to-BART. Given the relatively limited
impact on visibility from these seven sources, we continue to agree
with Wyoming that 0.5 deciviews is a reasonable threshold for
determining whether its BART-eligible sources are subject-to-BART. In
addition, the commenter points to the impacts from oil and gas at Class
I areas. The BART Guidelines do not require states to consider the
impacts from sources other than BART-eligible sources when defining the
threshold for determining what sources are subject-to-BART. While the
Guidelines first say that, in setting a contribution threshold, states
should consider the number of ``emissions sources'' affecting the Class
I area at issue, the Guidelines then go on to clarify that states may
use a lower contribution threshold based on the location of a large
number of ``BART-eligible'' sources within the State that are proximate
to the Class I area at issue.
E. Reasonable Progress
1. RPGs
Comment: 40 CFR 51.308(d)(1) of the RHR requires states to
establish goals (in deciviews) that provide for reasonable progress
towards achieving natural visibility conditions for each Class I area
of the state. These are goals, not standards. Goals are typically
understood as levels aimed for but not necessarily met. Early on in the
process, EPA considered setting ``presumptive targets'' but eliminated
them before the final rule. EPA also says that the RPGs established by
the state are not directly enforceable. In spite of this, EPA has
proposed to FIP the Wyoming RPGs.
EPA does not specifically define the word ``goal,'' but the RHR
does describe what must be considered when the goals are set. Wyoming
has set six reasonable progress goals and every one of them met that
criteria. EPA does not even argue with this basic fact. When setting
the goals, the state must do a reasonable progress analysis. The State
of Wyoming complied with this requirement as well.
Response: EPA disagrees with this comment. Wyoming's selected RPGs
do not meet the requirements of the RHR. In establishing RPGs, Wyoming
must make two demonstrations. First, the State must demonstrate how the
four statutory reasonable factors, as applied to potentially affected
sources, were taken into consideration in selecting the goals. 40 CFR
51.308(d)(1)(i). In addition, if Wyoming establishes an RPG that
provides for a slower rate of improvement than the URP, the State must
demonstrate, based on the four statutory reasonable progress factors,
that achieving the URP is not reasonable and that the selected RPG is
reasonable. 40 CFR 51.308(d)(1)(ii). In determining whether the
selected RPGs in fact provide for reasonable progress towards natural
visibility conditions, EPA must evaluate these two demonstrations. 40
CFR 51.308(d)(iii).
EPA's interpretation of the statute and the RHR is that BART
sources should also be identified as anthropogenic sources of
visibility impairment for purposes of developing the long-term
strategy. 40 CFR 51.308(d)(3)(iv). Correspondingly, BART sources should
be considered ``potentially affected sources'' and evaluated for
controls using the reasonable progress factors. See 40 CFR
51.308(d)(1)(i)(A). However, due to the similarity of the reasonable
progress and BART factors, it is reasonable for states to rely on their
BART determinations to fulfill the requirements of 51.308(d)(1)(i)(A)
and 51.308(d)(1)(ii) (if applicable), in other words to demonstrate
that the reasonable progress factors were reasonably considered for
those sources for the first planning period. This interpretation is
consistent with guidance EPA has issued for states regarding meeting
reasonable progress requirements.\237\ However, the Wyoming submittal
states that the reasonable progress ``four factor analysis . . . is a
method for evaluating potential control strategies for facilities that
are not eligible for Best Available Retrofit Technology (BART) or
better-than-BART programs.'' Wyo. 309(g) Submittal at 115. Thus, the
Wyoming submittal on its face fails to meet the requirements of the
statute and the RHR. To the extent that Wyoming can be said to have
relied on its BART determinations to establish that the State
reasonably considered the reasonable progress factors for those
sources, that reliance fails for those sources for which we are
disapproving the BART determinations. In addition, as the State's RPGs
fall short of the URP, the State failed to adequately demonstrate,
based on the four statutory reasonable progress factors, that achieving
the URP was not reasonable and that, the selected RPG is reasonable.
Given our evaluation of these demonstrations, we have determined that
the selected RPGs do not provide for reasonable progress towards
natural visibility conditions.
---------------------------------------------------------------------------
\237\ US EPA, Office of Air Quality Planning and Standards,
Guidance for Setting Reasonable Progress Goals Under the Regional
Haze Program (June 1, 2007).
---------------------------------------------------------------------------
In addition, although we are not disapproving the State's ultimate
determination to not impose controls on non-BART sources, we note that
(as explained in more detail below) the State unreasonably relied on
impermissible factors to reach those determinations. Thus, the State
failed to demonstrate that it was reasonable, based on consideration of
the statutory reasonable progress factors, to not meet the URP. In
other words, although we are approving the State's decision as part of
its long-term strategy to not
[[Page 5197]]
impose controls on the non-BART sources the State listed, we are still
disapproving the State's RPGs.
Because the State failed to meet the requirements of
51.308(d)(1)(i) and (ii) when the State selected its RPGs as part of
the State's Regional Haze SIP, EPA is obligated to promulgate a
regional haze FIP to meet those requirements. That the RPGs are named
``goals,'' not standards, and are not directly enforceable is
irrelevant to this obligation.
Comment: Wyoming explained to EPA that Wyoming could not compel
these reasonable progress sources to put on controls without a State
rule, and that rule would have to include a visibility impact analysis.
Wyoming was willing to commit to developing such a rule in the next
planning period, but it did not have the time or resources left to
complete that task and get the SIP submitted to the EPA for the first
planning period. Wyoming's administrative rulemaking process requires
about nine months to a year to develop and finalize rules. Wyoming
believes that it has taken an important first step in the process, and
it appears to be more than many other states were making.
Wyoming also believes that it made more sense to develop a
comprehensive State reasonable progress rule that could be used for the
next SIPs to address regional haze. That rule would take extra time
that EPA was not willing to give the State. EPA told the State
repeatedly that ``The Regional Haze Rule does not allow for commitments
to potentially implement strategies at some later date that are
identified under reasonable progress.'' The State is still dumbfounded
by this kind of response for a rule that goes out to 2064, especially
where EPA itself has recognized the one-step-at-a-time doctrine.
Response: EPA disagrees with this comment. While we understand the
State's position on its limits on its authority, time, and resources,
EPA first promulgated the reasonable progress requirements under the
RHR on July 1, 1999, and we issued our guidance on setting RPGs in
September 2007. Wyoming submitted its Regional Haze SIP on January 12,
2011. Wyoming does not explain why the State did not have an adequate
amount of time to develop a regional haze SIP that meets the
requirements for reasonable progress.
In any case, the State's limits on its authority, time, and
resources are not permissible factors for EPA to take into account when
assessing the State's Regional Haze SIP. Instead, we must assess
whether it meets the requirements of the RHR, and in particular the
requirements for reasonable progress towards natural visibility
conditions. We note that we are approving certain portions of Wyoming's
Regional Haze SIP with respect to reasonable progress requirements.
To the extent that the notion of ``one-step-at-a-time'' is relevant
in this context, as explained elsewhere, Wyoming's Regional Haze SIP
fails to adequately make the very first step towards natural visibility
conditions: Achieving reasonable progress during the first planning
period. A commitment to completing that first step in a future planning
period cannot substitute for actually completing the first step within
schedule. Wyoming cites no authority to the contrary; conditional
approval under CAA section 110(k)(4) does not apply as Wyoming has made
no commitment to adopt specific enforceable measures within one year to
remedy the deficiencies. Again, whatever the constraints imposed on the
State by time, resources, and authority, those constraints cannot be
taken into account in assessing whether the State has met the
requirements for the first planning period. In this case, Wyoming has
not met those requirements with respect to reasonable progress.
Comment: States are required, when setting RPGs, to determine the
rate of progress needed to attain natural visibility conditions by
2064. The State did that and included it in the SIP. EPA's RHR also
requires that if the rate is slower than the rate established by
drawing a straight line between baseline visibility and natural
conditions, that it must be explained why. The data clearly show that
the primary reason that the State will not reach natural conditions by
2064 is that smoke from wildfires controls the slope of the line.
Response: EPA disagrees with this comment, which understates the
requirements of the RHR for setting RPGs. We agree that Wyoming did
appropriately determine the URP needed to attain natural visibility
conditions by 2064 and we are approving that determination. However,
when a state selects an RPG that provides for a slower rate of
improvement in visibility than the URP, it is not the case that all the
state must do is ``explain why.'' Instead, the state must demonstrate,
based on the statutory reasonable progress factors as applied to
potentially affected sources, that the URP is not reasonable and that
the selected RPG is reasonable. 40 CFR 51.308(d)(1)(ii). Under the RHR,
40 CFR 51.308(d)(1)(iii), and under section 110 of the Act (as
discussed elsewhere) we are required to evaluate the state's
demonstration.
As discussed elsewhere, the State did not reasonably consider the
statutory reasonable progress factors for potentially affected sources.
As a result, the State also failed to adequately demonstrate, based on
the four statutory reasonable progress factors as applied to
potentially affected sources, that achieving the URP was not reasonable
and that the selected RPG is reasonable. We therefore are disapproving
Wyoming's selected RPGs.
With respect to the comment's reference to wildfires, we provide a
detailed response to comments relating to wildfires and natural
conditions in the modeling section of this response to comments.
Comment: EPA cannot remove the reasonable progress goals for the
State. Wyoming followed the process outlined in the RHR. EPA is not
following the RHR by proposing a control requirement for a specific
source to replace six RPGs for an entire state. The RHR does not allow
for the substitution of RPGs with control strategies. EPA's proposed
disapproval is contrary to law.
Response: EPA disagrees with this comment. As discussed above, we
are disapproving the State's selected RPGs because they do not meet the
requirements of the RHR. In addition, the commenter is mistaken in
stating that EPA is ``replacing'' RPGs with control requirements for a
specific source. This statement conflates two separate but related
requirements of the RHR. First, states must set RPGs in accordance with
40 CFR 51.308(d)(1). Second, states must submit a LTS, including
enforceable emissions limitations, compliance schedules, and other
measures as necessary to achieve the RPGs. 40 CFR 51.308(d)(3).
We are disapproving Wyoming's RPGs because they do not meet the
requirements of 51.308(d)(1), as detailed above. Separately, we
proposed to disapprove Wyoming's determination to not impose
enforceable emissions limitations at Dave Johnston Units 1 and 2. Thus,
we did not propose to ``replace'' the RPGs with control requirements;
instead, we proposed to provide both. However, as explained elsewhere,
on the basis of the cost and visibility information that EPA developed,
we are now approving Wyoming's determination (although not the State's
rationale) to not impose enforceable emissions limitations at Dave
Johnston Units 1 and 2. We nonetheless continue to disagree with the
comment.
Comment: There is no way Wyoming can control the impacts from
wildfire
[[Page 5198]]
smoke on visibility. Therefore, it will be a very long time, 126 to 161
years, before controlling manmade sources can ever overcome the smoke
impacts, and that is assuming that smoke impacts never increase. The
length of time for other western states is even longer, and EPA has
approved those SIPs. Wyoming included this explanation along with
identifying other sources that impact visibility, but EPA disagreed
with the Wyoming assessment, saying not all reasonable controls were
implemented during the first planning period. Specifically, EPA
disagreed with Wyoming's determination to not impose controls on Dave
Johnston Units 1 and 2. Because Wyoming did not impose controls on Dave
Johnston Units 1 and 2, EPA has proposed to disapprove Wyoming's RPGs.
Wyoming believes that EPA's reasoning for disapproving the State's
RPGs is flawed and arbitrary. First, the State set goals based on
regional modeling projections done for the entire western U.S. To the
best of our knowledge, that is the same process that every other state
in the western U.S. used and many of them now have approved RPGs in
spite of the fact that it will take hundreds of years in all of the
western Class I areas to reach ``natural conditions.'' In North Dakota,
for example, it will take between 156 and 232 years to reach natural
conditions at affected Class I areas. It would be impossible to set
deciview goals without regional modeling, unless the State wanted to
wildly guess at it.
Response: EPA disagrees with this comment. We are not disapproving
Wyoming's RPGs solely on the basis that they fall short of achieving
the URP. Instead, as explained above, we are disapproving them on the
basis that the State has failed to demonstrate that the four statutory
reasonable progress factors were appropriately considered. The State
has also failed to demonstrate, again based on the four statutory
reasonable progress factors, that achieving the URP is unreasonable and
that the State's selected RPGs are reasonable. The comment's reference
to wildfires is beside the point, as the existence of wildfires does
not relieve the State of all responsibility to reasonably consider the
statutory reasonable progress factors for potentially affected sources.
We elsewhere provide a detailed response to comments relating to
wildfires and natural conditions in the modeling section of this
response to comments.
Comment: While EPA ``anticipates'' that controls at Dave Johnston
Units 1 and 2 would result in measurable visibility improvement in
regional modeling demonstrations, and that ``anticipation,'' not
modeling, therefore justifies dispensing with Wyoming's RPGs, Wyoming
does not. When the WRAP modeled all of the emission reductions from the
entire western U.S. (including Wyoming emission reductions for all of
the pollutants) for this first planning period, Wyoming saw an
improvement of 0.6 deciviews at the Yellowstone site, and a 0.5
deciview improvement at the North Absaroka and Bridger sites on the
worst days. The numbers are even smaller or zero for the best days.
These improvements from much larger emission reductions for multiple
pollutants are almost imperceptible. Therefore, it is highly unlikely
that emission reductions for NOX from two units would make
enough difference to show up as an ``improvement'' in regional scale
modeling, and thereby justify setting different RPGs.
Response: We disagree with the approach suggested in this comment.
Below, we discuss the use of CALPUFF (instead of the regional scale
modeling the comment suggests) to determine visibility improvement from
controls on Dave Johnston Units 1 and 2. We also respond to comments
regarding regional scale modeling in section V.B.
Comment: The EPA proposes to impose reasonable progress controls on
Dave Johnston Units 1 and 2, more stringent NOX BART
controls on Dave Johnston Unit 3, Jim Bridger Units 1 and 2, Wyodak
Unit 1, and Laramie Units 1, 2, and 3. These EPA proposed controls are
more stringent than what was assumed by the WRAP in modeling Wyoming's
RPGs. Wyoming established its RPGs based on the regional modeling
projections completed in the WRAP process. In proposing these
reasonable progress controls, EPA is also proposing RPGs that are
consistent with the controls, thereby rejecting Wyoming's proposed
RPGs.
In rejecting Wyoming's RPGs and imposing its own, EPA did not re-
run the WRAP model; instead, the agency essentially guessed ``that the
additional controls would result in an increase in visibility
improvement during the 20% worst days,'' thereby warranting the more
stringent controls at these units.
EPA's proposal to reject Wyoming's RPGs is not warranted. First,
the mere assumption that additional controls will result in greater
visibility improvement cannot reasonably be supported without modeling
data. EPA admits that it ran no modeling that would support its best
guess that visibility would improve with the installation of more
stringent controls. Second, EPA's proposal to place controls on the
Dave Johnston Units 1 and 2 is flawed. The Dave Johnston Units 1 and 2
are not BART-eligible units. When Wyoming considered the WRAP model
data, it concluded that putting controls on the Dave Johnston Units 1
and 2 would not result in an improvement in visibility. Without any
improvement in visibility coming from placing controls on these non-
BART units, Wyoming reasonably concluded that there was no reason to
change its RPGs.
Response: We disagree with this comment. WRAP performed regional
photochemical modeling using both the CMAQ and CAMx air quality models
to evaluate progress toward attaining visibility goals using all
projected emission changes from all source categories throughout the
United States. WRAP did not perform regional photochemical modeling to
evaluate the visibility impacts of individual BART sources. While WRAP
did make assumptions regarding the level of emissions control that
would be adopted by BART sources, no state or EPA region has re-run the
WRAP's regional photochemical models to assess individual BART source
contributions to visibility impairment. Instead, the BART sources, the
states, and EPA have used the CALPUFF model to evaluate contributions
to visibility impairment from individual BART sources. As discussed
earlier in this rulemaking and the docket for this final action, EPA
modeled visibility impairment from individual sources in making its
determination of BART and reasonable progress controls. Thus, the
comment is inaccurate in stating that EPA ran no modeling to assess
whether controls on Dave Johnston Units 1 and 2 would improve
visibility. With respect to the assertion that Wyoming considered the
WRAP model data and decided that the data showed controls on Dave
Johnston Units 1 and 2 would not improve visibility, the Wyoming SIP
submittal does not reflect that. In evaluating the reasonable progress
factors for Dave Johnston Units 1 and 2 (which was selected by the
State as a potentially affected source) the SIP submittal states: ``LNB
or LNB w/OFA seem to be the most reasonable choice[s] for the Dave
Johnston Electric Generating Station boilers BW41 and BW42 based on the
four factor analysis. The implementation of new control technologies on
the two boilers are discussed in further detail in Chapter 8 (Section
8.3.4), Long-Term Strategy.'' Nonetheless, in section 8.3.4, the SIP
stated: ``The Air Quality Administrator cannot, per Wyoming Statute 35-
11-202, establish emission control
[[Page 5199]]
requirements except through State rule or regulation. Furthermore, the
Wyoming statute requires the Administrator to consider the character
and degree of injury of the emissions involved. In this case,
visibility modeling would be required to assess the degree of injury
caused by the emissions. Modeling is not available at this time to
determine impacts from emission reduction.'' As we explain elsewhere,
these are not permissible reasons to ignore the four statutory
reasonable progress factors. Nonetheless, our revised visibility
modeling leads us to the conclusion that it was not unreasonable for
the State to not impose controls on Dave Johnston Units 1 and 2, even
though the State's basis for doing so was inadequate.
Comment: Wyoming's adoption of an alternative SO2
program, even if it were valid, does not relieve Wyoming of its
obligation to develop and implement a LTS that includes measures
necessary to reduce visibility-impairing emissions of SO2,
PM, and NOX to achieve RPGs for non-Colorado Plateau Class I
areas. Accordingly, EPA must determine whether Wyoming's RPGs for its
non-Colorado Plateau Class I areas are adequate.
Response: We agree that Wyoming must develop a LTS to address
reasonable progress for non-Colorado Plateau Class I areas. As our
proposed notice indicates, we proposed to disapprove the State's RPGs.
We also proposed to implement additional controls under reasonable
progress. We are completing the action to disapprove the State's RPG's
today, and as explained elsewhere in this section, we are not
finalizing requirements for additional controls under reasonable
progress.
Comment: With the exception of the controls required on Naughton
Unit 3, PacifiCorp has installed all of the BART controls required by
the Wyoming BART permits and the regional haze SIP. These controls were
installed from 2005 through 2012. The actual monitored visibility
impairment demonstrates that Wyoming has made significant progress in
reducing nitrate concentrations and further demonstrates that the RPGs
are on track through the 2008-2017 planning period. EPA's FIP is not
``necessary'' to meet RPGs for nitrates in these Class I areas. As a
result, EPA should withdraw its FIP.
Response: EPA disagrees with this comment. As explained above, the
State was required to assess the four statutory reasonable progress
factors for potentially affected sources and reasonably determine
potential controls, and we are required to evaluate the State's
determination. The State did not demonstrate reasonable progress for
those determinations that we are disapproving. As a result, we must
disapprove the State's RPGs and promulgate a FIP for them. We also note
that the comment does not explain the relationship between the State's
RPGs and changes in monitored visibility impairment as the result of
installed controls, as the State's RPGs were not remodeled to reflect
the controls selected by the State.
Comment: Any discussion of the appropriate NOX control
levels required under the RHR should include an assessment of the
existing visibility levels to understand what pollutants are driving
visibility impairment in Wyoming. Measured visibility impairment at
Wyoming's IMPROVE monitoring stations shows that the contribution from
nitrates, which are visibility impairing pollutants that result from
NOX emissions, play a lesser role in visibility impairment
in Wyoming than particulate organic mass or sulfates. The latest
available IMPROVE data (2000-2009) from the WRAP Technical Support
System reveals the following about the two Class I areas that were most
closely examined for impacts from Wyoming BART sources: (1) Currently,
the air in those Class I areas is very clear, with overall visibility
among the best in the entire country; (2) When visibility is not good,
i.e., when you can't see across the vista, it is likely because of
smoke from wildfires; (3) The contribution to visibility impairment
from nitrate particles, which are as a result of emissions of
NOX, is small.
The State believes it has made a good case that fire contributes
more to visibility impairment than nitrates at Class I areas most
affected by Wyoming sources. The State has made great progress in
reducing the manmade contribution to visibility impairment from power
plants, even when the manmade contribution has much less impact to
visibility impairment than other components. EPA's proposed disapproval
and FIP are not supported by a record that demonstrates small
visibility improvements predicted by a CALPUFF model replete with
uncertainty when the actual, measured levels of nitrates at Class I
areas affected by those sources is so small. Wyoming's SIP is
adequately supported because Wyoming considered these and other factors
in arriving at the selected levels of NOX controls for
Wyoming sources and the schedule for the installation of those
controls.
Response: We disagree with this comment. Regardless of the
considerations presented in the comment, the State was required, at a
minimum, to evaluate the four statutory reasonable progress factors for
potentially affected sources and to reasonably determine controls, and
we are required to evaluate the State's determination. In evaluating
the factors for Dave Johnston Units 1 and 2, which was selected in the
State's SIP as a potentially affected source, the SIP submittal states:
``LNB or LNB w/OFA seem to be the most reasonable choice[s] for the
Dave Johnston Electric Generating Station boilers BW41 and BW42 based
on the four factor analysis. The implementation of new control
technologies on the two boilers are discussed in further detail in
Chapter 8 (Section 8.3.4), Long-Term Strategy.'' Nonetheless, in
section 8.3.4, the SIP stated: ``The Air Quality Administrator cannot,
per Wyoming Statute 35-11-202, establish emission control requirements
except through State rule or regulation. Furthermore, the Wyoming
statute requires the Administrator to consider the character and degree
of injury of the emissions involved. In this case, visibility modeling
would be required to assess the degree of injury caused by the
emissions. Modeling is not available at this time to determine impacts
from emission reduction.''
As explained above, it is unreasonable and impermissible for the
State to disregard its four factor analysis on the basis that the State
lacked the necessary modeling and that reasonable progress requirements
could be postponed until the next planning period. The considerations
presented by the comment do not change this.
In addition, section 110(a)(2)(E)(i) of the Act requires that SIPs
provide necessary assurances that, among other things, the State has
adequate authority and resources to carry out the plan. The SIP
language we quote above instead denies that the State has the proper
authority and resources to meet the requirements of the RHR, in
particular the requirement that the long-term strategy ``include
enforceable emissions limitations . . . and other measures as necessary
to achieve the reasonable progress goals.'' 40 CFR 51.308(d)(3). As a
result, Wyoming's Regional Haze submittal fails to meet the
requirements of section 110(a)(2)(E)(i), which is applicable to
``[each] implementation plan submitted by a State under [the CAA],''
including the Regional Haze submittal.
Comment: An area of the RHR that is unusual is in the timing of the
implementation of the rule. It is the most forward looking of all the
rules
[[Page 5200]]
with requirements to be carried out by the grandchildren of the people
who are currently working on the rule, with an end date of 2064. While
EPA has established long-term targets through the acid rain program and
ozone attainment requirements in a 10-20 year time frame, they have
never set goals that were 60 years down the road. This is significant
because EPA recognized that the problem was complicated and that it
would take at least this much time to solve it.
EPA's strategy included breaking up the long-range goal of
achieving natural conditions by 2064 into many smaller pieces. EPA
included a requirement for states to submit comprehensive SIP revisions
in 2018 and every ten years thereafter. In addition to the
comprehensive SIP revisions, states will also be required under 40 CFR
51.308(g) to submit progress reports in the form of a SIP revision
every five years, with the first revision due in 2013. Between both the
comprehensive SIP revisions and the progress report SIP revisions,
states will be working on 16 more SIP revisions, at a minimum, to
address regional haze. The State views these upcoming SIP revisions on
regional haze as opportunities to build on the first SIP, and that the
current rush by the EPA to get so many reductions procured in the first
time period as unnecessary. It is unnecessary because the State has
submitted a plan to reduce NOX from BART sources by 45,153
tons, and an additional 19,677 tons through the LTS in the first
planning period. There are few states in the country that can
demonstrate this magnitude of emission reductions Wyoming has secured.
EPA recognized in the RHR preamble that many factors will change
over time and that it may be possible to procure emission reductions in
the future that cannot be accomplished during an earlier period. EPA
expected reductions to occur over time and did not expect states to
front end load this program with emission reductions.
The RHR provides states with the time necessary to intelligently
address the very complicated problem of regional haze. Wyoming asks EPA
to recognize their own intentions to roll out this program step by step
and approve the State's decision to require SCR on PacifiCorp Units 1
and 2 of the Jim Bridger Power Plant in 2021 and 2022 as part of the
LTS. The State also asks that EPA give the State the time it needs to
create a rule to address reasonable progress, which would include
reductions at the PacifiCorp Dave Johnston Plant, Units 1 and 2.
Wyoming plans to create a general reasonable progress rule in the next
planning period to address future reductions.
Response: While we recognize the emission reductions achieved by
the State for the first planning period and that the regional haze
program is a long-term program, the State must still meet the
requirements of 40 CFR 51.308 for the first planning period. As we
stated in our proposal notice, the State's plan does not fully meet the
requirements for BART and reasonable progress. Because we have found
that the State's SIP submission did not adequately satisfy the RHR
requirements in full, we have not only the authority, but a duty to
promulgate a FIP that meets those requirements. The EPA disagrees that
the additional emission reductions required by our proposed FIP are
unnecessary, as we have demonstrated that the State's SIP does not meet
the requirements of 40 CFR 51.308. Our FIP action is only intended to
ensure that CAA requirements are satisfied in accordance with our
authority under the CAA.
Comment: We received numerous comments that monitoring data shows
that the worst visibility days are due to wildfires and that EPA should
be focusing on these emissions and not on nitrate emissions from
stationary sources, which have little impact on poor visibility days.
One commenter pointed out data from Class I areas in Wyoming that show
organic carbon and elemental carbon, which are indicators of wildfire,
are major contributors on poor visibility days compared to nitrates.
Another commenter stated that the only EPA policy to address fires is
the Interim Air Quality Policy on Wildland and Prescribed Fires which
has not been updated since 1998 and that the EPA is not taking action
on this core issue.
Response: While we agree that industrial facilities are not the
only causes of haze, we disagree with the thrust of this comment. We
provide a detailed response to comments relating to wildfires and
natural conditions in the modeling section of this response to
comments. Regardless of the contribution from wildfire emissions, 40
CFR 51.308(d)(3)(iv) states, ``The State must identify all
anthropogenic sources of visibility impairment considered by the State
in developing its long-term strategy. The State should consider major
and minor stationary sources, mobile sources, and area sources.'' As
discussed elsewhere, in its submittal the State identified a number of
stationary sources as potential contributors to visibility impairment
(i.e. potentially affected sources). The State was required, at a
minimum, to evaluate the five statutory BART factors and four statutory
reasonable progress factors for potentially affected sources and to
reasonably determine controls, and we are required to evaluate the
State's determination. 40 CFR 51.308(e) and 40 CFR 51.308(d)(3)(iv),
respectively. The requirements of 40 CFR 51.308(d)(3)(iv) and 40 CFR
51.308(e) are not dependent on the showing of a certain amount of
impairment from point sources.
Comment: The CAA and the RHR require SIPs to set forth goals,
expressed in deciviews, that assure ``reasonable progress toward
meeting the national goal'' of ``natural visibility conditions [in
Class I areas] by the year 2064.'' 42 U.S.C. 7491(a)(4), (b); 40 CFR
51.308(d)(1)(i)(A). The goals ``must provide for an improvement in
visibility for the most impaired days over the period of the
implementation plan and ensure no degradation in visibility for the
least impaired days over the same period.'' 40 CFR 51.308(d)(1). To
establish these goals, a state must also ``[a]nalyze and determine the
rate of progress needed to attain natural visibility conditions by the
year 2064,'' by ``compar[ing] baseline visibility conditions to natural
visibility conditions [in Class I areas] and determin[ing] the uniform
rate of visibility improvement'' necessary to achieve natural
conditions by 2064. 40 CFR 51.308(d)(1)(i)(B).
Wyoming's SIP meets these requirements. See SIP, at 114-31. The SIP
calculates and compares baseline and natural visibility conditions, Id.
at 114-15, analyzes the rate of progress needed to attain natural
visibility conditions by 2064, Id., and establishes a uniform rate of
progress, Id. Wyoming also ensured improvement in visibility on the
most impaired days and no degradation on the least impaired days. See
Id. at 115 (Table 7.2.1). And, most importantly, the SIP establishes
reasonable progress goals. Id. at 127-131. The CAA and the RHR also
require states to make reasonable progress determinations for
particular sources by ``[c]onsider[ing] the costs of compliance, the
time necessary for compliance, the energy and non-air quality
environmental impacts of compliance, and the remaining useful life of
any potentially affected sources, and includ[ing] a demonstration
showing how these factors were taken into consideration in selecting
the goal.'' 40 CFR 51.308(d)(l)(i)(A).
Wyoming also met this requirement. The SIP clearly explains how
Wyoming considered these factors and identified sources impacting
visibility in Class I areas. See SIP, at 116-17. Wyoming then
[[Page 5201]]
explained in its SIP how it applied the factors to each individual
source. See Id. at 117-27. The SIP therefore meets the requirements of
the Act and the RHR.
Response: As discussed elsewhere, we have evaluated Wyoming's BART
and reasonable progress determinations and we are disapproving them for
Dave Johnston Unit 3, Wyodak Unit 1, and Laramie River Station Units 1-
3. Because the State did not reasonably consider the statutory BART
factors for these sources, the State also failed to adequately
demonstrate (to the extent that the State relied on its BART
determinations to demonstrate the required consideration of the
reasonable progress factors) that the reasonable progress factors were
appropriately considered in establishing the RPGs. The State also
failed to adequately demonstrate, based on the statutory BART and
reasonable progress factors, that achieving the URP was not reasonable
and that the selected RPG is reasonable. Given our evaluation of these
two demonstrations and the comments received, we have determined that
the selected RPGs do not provide for reasonable progress towards
natural visibility conditions.
In making this determination, we are not limited to merely noting
whether the State has submitted an analysis that purports to consider
the BART and reasonable progress statutory reasonable progress factors.
Instead, we evaluate whether the State reasonably assessed the
statutory BART and reasonable progress factors as applied to
potentially affected sources and, based on those factors, reasonably
determined whether controls were required for this planning period. In
this case, the State did not do so.
As discussed earlier, because the State failed to meet the
requirements of Sec. 51.308(d)(1)(i) and (ii) when the State selected
its RPGs as part of the State's Regional Haze SIP, EPA is obligated to
promulgate a regional haze FIP to meet those requirements.
We do agree that the State did correctly calculate and compare
baseline and natural visibility conditions, analyzed the rate of
progress needed to attain natural visibility conditions by 2064, and
established a URP. We agree that Wyoming's SIP ensured improvement in
visibility on the most impaired days and no degradation on the least
impaired days, as does our FIP.
Comment: EPA acknowledges that Wyoming evaluated the requisite four
factors in its reasonable progress determinations. 78 FR 34785. But,
EPA asserts that Wyoming incorrectly calculated costs in those
determinations. Id. EPA, however, does not explain how Wyoming
incorrectly calculated costs. EPA asserts first that ``EPA's rationale
for disapproving the State's reasonable progress determination[s] . . .
can be found in Section VIII.B of [the proposal].'' ld. at 34763.
Section VIII.B--the location of EPA's supposed ``rationale''--only
reiterates EPA's general allegation of deficiencies in the control cost
estimates. Id. at 34785. EPA therefore has not described with any
meaningful degree of specificity the supposed errors that justify
rejecting the State's reasonable progress determinations. EPA's failure
to provide an intelligible justification for its action is unlawful and
arbitrary, and precludes Wyoming from offering a more meaningful
response.
Response: We disagree. First, the commenter fails to fully disclose
EPA's proposed rationale for disapproving the State's reasonable
progress determination for Dave Johnston Units 1 and 2. The commenter
cites language related to our finding of deficiencies with the State's
cost analysis (at 78 FR 34785), but fails to cite our fuller
explanation for disapproving the State's determination a few pages
later (at 78 FR 34787): ``We disagree with the State's reasoning for
not adopting reasonable progress controls for Dave Johnston Unit 1 and
Unit 2. If the State determined that it needed to adopt a rule or
perform modeling to adequately assess and, if warranted, require
reasonable progress controls, the State should have completed these
steps before it submitted its regional haze SIP. The RHR does not allow
for commitments to potentially implement strategies at some later date
that are identified under reasonable progress or for the State to take
credit for such commitments.''
We offered this rationale in response to the State's argument that
no controls were reasonable because: (1) the State's four factor
analysis was limited, in that no guidance was provided by EPA for
identifying significant sources and EPA did not establish contribution
to visibility impairment thresholds (a potential fifth factor for
reasonable progress determinations), (2) the State cannot, per Wyoming
Statute 35-11-202, establish emission control requirements except
through State rule or regulation, (3) the Wyoming statute requires the
State to consider the character and degree of injury of the emissions
involved--information that State claimed not to have, and (4) the State
believes it has taken a strong and reasonable first step in identifying
potential contributors to visibility impairment, and that the next step
of creating an appropriate rule or regulation will be accomplished in
the next SIP revision. 78 FR 34786. Therefore, our proposed rationale
for disapproving the State's reasonable progress determination for Dave
Johnston extended beyond our concerns with the cost analysis.
Even so, contrary to the commenter's assertions, and though perhaps
not to the level of detail desired by the commenter, we did
sufficiently explain our concerns with deficiencies in Wyoming's cost
analyses, including those for Dave Johnston Units 1 and 2. Most
notably, as described in Section VII.C of the proposed rule, we
recognized that Wyoming had understated ``the ability of SCR to reduce
NOX.'' This was most pronounced at Dave Johnston Units 1 and
2 where the State assumed that SCR would only reduce NOX to
an emission rate of about 0.09 lb/MMBtu (equivalent to an 80% reduction
from 2001-2003 baseline). As we have established elsewhere in response
to comments, in this instance SCR has the ability to reduce
NOX to an emission rate of 0.05 lb/MMBtu or less. Therefore,
it is clear that the State underestimated the emission reductions that
can be achieved with SCR, and thereby miscalculated the cost
effectiveness. And while EPA did not find that SCR was warranted for
Dave Johnston Units 1 and 2, it was nonetheless necessary to correctly
calculate the cost effectiveness of all of the technically feasible
controls in order to rationally evaluate the State's decision to not
impose any controls and to (had we been compelled to impose a FIP)
select from among competing control options.
Comment: The RHR clearly states that every implementation plan must
include reasonable progress goals. 40 CFR 51.308(d)(l). Those goals
must be expressed in deciviews and must provide for visibility
improvement on the most impaired days and no degradation on the least
impaired days during the planning period. Id. In EPA's own words, RPGs
are ``[t]he vehicle for ensuring continuing progress towards achieving
the natural visibility goal,'' 78 FR 34743, which is the focal point of
the regional haze program, see 42 U.S.C. 749l(a)(l).
EPA proposes to disapprove the State's reasonable progress goals.
78 FR 34767. In the same sentence, EPA claims to be proposing a FIP to
replace those goals, which EPA asserts can be found in Section VIII.C
of the notice. Section VIII.C reveals, however, that EPA has in fact
failed to establish replacement RPGs. See Id. at 34788.
[[Page 5202]]
EPA does not set forth RPGs in deciviews, nor does it provide for
visibility improvement on the most impaired days with no degradation on
the least impaired days. See Id. Instead, EPA merely ``anticipates''
that its FIP would lead to improved visibility. Id. EPA's anticipation
falls far short of the plain requirements of the RHR--concrete,
deciview-based reasonable progress goals that provide for improved
visibility on the worst days and no degradation on the best days. EPA's
failure to establish RPGs to replace the SIP goals EPA proposes to
disapprove is therefore unlawful.
EPA justifies its failure to establish the requisite RPGs by
explaining that it ``could not re-run the modeling due to time and
resource constraints [.]'' Id. This excuse stands in stark contrast to
EPA's response to similar claims the State raised in the context of
reasonable progress. For example, the State explained to EPA that the
State could not complete its evaluation of the impacts to visibility
from oil and gas sources until the WRAP completes its emission
inventory study. Id. at 34764-34765. EPA responded that ``If the State
determined that additional information was need . . . the State should
have developed the information.'' Id. at 34765. Similarly, the State
explained to EPA that it needed to conduct additional modeling before
it could justify controls for the Mountain Cement kiln. Id. at 34765-
34766. Again setting forth its dual standard, EPA responded that ``If
the State determined that it needed to adopt a rule or perform modeling
. . . the State should have completed these steps before it submitted
its regional haze SIP.'' Id. at 34766.
Response: EPA disagrees with this comment to the extent it argues
that we should approve the State's RPGs. We note that the State did
not, in setting its RPGs, re-run its modeling to reflect the State's
selected controls. Instead, the State relied on WRAP modeling that
reflected certain generic assumptions about the level of controls. See
Wyo. 309(g) SIP, pages 53 and 127. As we have explained elsewhere,
regardless of how the State quantified its RPGs, they cannot be
approved, as the State failed to appropriately consider the four
statutory reasonable progress factors for the sources the State
selected as potentially affected sources. See 40 CFR
51.308(d)(1)(i)(A). In addition, the State cannot rely on the BART
determinations that we are disapproving to show reasonable progress for
those sources. Because we must disapprove the State's RPGs, and RPGs
are a required component of a regional haze SIP, we must promulgate our
own. We note that the RPGs are not directly enforceable. 40 CFR
51.308(d)(1)(v). The elements that directly impact sources and
visibility are the emissions limitations in the long-term strategy,
including those for BART and those for the reasonable progress sources.
Comment: When determining the responsibility for regional haze,
Sweetwater County strongly believes that the DEQ and EPA need to
investigate the contribution to Wyoming's haze problem by sources
located outside of the United States, especially from countries like
China that do not appreciate the necessity for strong environmental
regulations. If we do not consider the effects of air pollution
contributing to our nation's and our State's air quality issues, we
open the door for unfair competition. To assign the entire cost of
Wyoming's haze and air pollution to Wyoming industries without
considering the effects of offshore sources is unfair to our
industries, and it would cause unnecessary impacts to the economy of
Wyoming and the United States.
Response: While sources outside Wyoming do contribute to haze in
the Class I areas within Wyoming, that does not preclude the State's or
our obligation to evaluate sources within the State according to the
five BART factors and the four reasonable progress factors and to
require additional controls where necessary. In addition, we note that
the State did evaluate the sources of contribution to Class I areas in
the State (see e.g., Chapter 5 of the SIP).
Comment: One commenter stated that EPA must re-evaluate its method
for assessing visibility impacts from wildfires or states will never be
able to achieve natural background goals. The commenter went on to say
that EPA should (1) eliminate the impacts from fire from the annual
contribution to the deciview analysis or (2) properly incorporate it
into the natural background equation to establish a glide path states
can achieve. The commenter provided graphical data from the IMPROVE
network to show the contributions to light extinction from organic
carbon, elemental carbon, and nitrate.
Response: EPA does recognize this issue and has taken it into
consideration in this action on the Wyoming SIP and in our final FIP.
We agreed that Wyoming did appropriately determine the URP needed to
attain natural visibility conditions by 2064 and we are approving that
determination. We are not disapproving Wyoming's RPGs solely on the
basis that they fall short of achieving the URP. Instead, as explained
above, we are disapproving them on the basis that the State has failed
to demonstrate that the four statutory reasonable progress factors were
appropriately considered. As stated previously, regardless of the
contribution from wildfire emissions, 40 CFR 51.308(d)(3)(iv) states,
``The State must identify all anthropogenic sources of visibility
impairment considered by the State in developing its long-term
strategy. The State should consider major and minor stationary sources,
mobile sources, and area sources.'' As discussed elsewhere, in its
submittal the State identified a number of stationary sources as
potential contributors to visibility impairment (i.e. potentially
affected sources) and was required, at a minimum, to evaluate the five
statutory BART factors and four statutory reasonable progress factors
for potentially affected sources and to reasonably determine controls,
and we are required to evaluate the State's determination. 40 CFR
51.308(e) and 40 CFR 51.308(d)(3)(iv), respectively.
2. Reasonable Progress Sources
a. Oil and Gas Sources
Comment: We received comments that volatile organic compound (VOC)
emissions from the oil and gas industry must be controlled under
reasonable progress. Commenters asserted that EPA acknowledged that oil
and gas sources emit haze-causing VOCs but inexplicably failed to
analyze whether reducing such VOC emissions is reasonable. One
commenter pointed out that EPA has just designated Sublette County (and
portions of Sweetwater and Lincoln Counties) in nonattainment with the
8-hour ozone national ambient air quality standard, so there is no
doubt the ozone levels in Sublette County are of great concern.
Commenters pointed out that ozone severely impairs visibility; the
failure to consider strategies to limit oil and gas industry VOC
emissions was a significant oversight on both the part of the State and
EPA. Thus, commenters concluded that EPA must correct this problem by
analyzing and imposing reasonable progress controls on oil and gas
industry VOC emissions.
Commenters pointed out that there are numerous opportunities to
reduce VOC emissions from the oil and gas industry. These include
requiring all oil and gas fields in the State to control VOC emissions
to the same extent currently required in the Pinedale Anticline and
Jonah fields pursuant to the State's BACT guidelines, implementing
recommendations from the Upper Green River Basin Air Quality
[[Page 5203]]
Citizens Advisory Task Force, and adoption of a statewide offset
program.
Response: We disagree with this comment. The commenters did not
provide any evidence of the impact of VOC emissions on visibility in
Class I areas.
Comment: Wyoming claims that regulation of drilling rigs is
problematic because drilling rigs are mobile sources over which states
have limited CAA authority. EPA is not similarly constrained and may
require emissions reductions from drilling rigs in a FIP. Replacement
of Tier 2 engines with Tier 4 engines on drilling rigs has a cost
effectiveness value as low as $900/ton, which is very reasonable.
Response: EPA disagrees with this comment. The costs noted by the
commenter for controls for drill rig engines are the lower end of the
costs presented by the State. For replacement of Tier 2 engines with
Tier 4 engines, the State presented costs of $900 to $2400 per ton of
NOX removed, but the commenter cited only the $900 per ton
figure. To the extent that drill rig engines could be regulated under
the RHR, this range of costs is not so low that we are prepared to
disapprove the State's determination in the reasonable progress
context.
Comment: EPA states it disagrees with the State's reasoning for not
adopting reasonable progress controls for the for oil and gas sources.
It is our view that, having made this finding, it is inappropriate for
EPA to then propose approval of the State's control plan, a plan which
would involve no new controls on the oil and gas sector. Having found
that the State's RPGs were not justified, the EPA must put in place a
FIP establishing RPGs for the oil and gas sector or ask the State to
revise its plan.
There are numerous available means for controlling NOX
from the oil and gas sector, which is the primary focus that EPA has.
For example, the State has begun regulating NOX emissions
from drill rigs on the Pinedale Anticline and Jonah Field. The State
has put in place a number of regulations on those drill rigs. We
believe there is no reason this could not be extended to other fields
in other portions of the state.
Response: We disagree with this comment. First, we did not propose
approval of the State's control plan in its entirety. Instead, we
proposed to disapprove the State's reasonable progress determination
for Dave Johnston Units 1 and 2; we also proposed to disapprove the
State's RPGs. We then proposed a FIP for the RPGs. While we are
approving the State's reasonable progress determination for Dave
Johnston Units 1 and 2, we are still finalizing a FIP for the RPGs, as
we have disapproved some of the State's BART determinations. Second, as
we stated in our proposal, although we disagree with the State's
reasoning with respect to the oil and gas sector, after considering the
costs presented by the State, we find that they are not so low that we
are prepared to disapprove the State's determination in the reasonable
progress context. With respect to NOX emissions generally
from the oil and gas sector, as discussed elsewhere, Wyoming applies
minor source BACT to these sources. For drill rig engines in
particular, see our response above. Finally, with respect to visibility
impacts of NOX emissions from oil and gas sources on Class I
areas, this comment provided no particular data. We respond below to
other comments on visibility impacts of oil and gas sources.
Comment: The State provided sound reasoning for not adopting
reasonable progress controls for oil and gas sources. Wyoming is an oil
and gas production state, along with Colorado, North Dakota, New
Mexico, Montana, and Utah. One of the biggest challenges faced by these
WRAP states has been to inventory the emissions from this industry. At
the beginning of the regional haze process, a comprehensive emission
inventory of oil and gas production operations in the western region
that covered both point and area sources had not been developed. No
methodology had been developed to produce an inventory of this scope.
The WRAP oil and gas states collaborated to develop and implement a
uniform procedure for estimating area source emissions from oil and gas
operations. WRAP initiated a study to focus on estimating emissions of
pollutants with the potential to impair visibility near Class I areas
in the West, particularly NOX emissions.
Developing this inventory has been one of the most important tasks
that needed to be completed before any of the western states could
begin to look at imposing controls for improving visibility. In
addition to developing these critical inventories, the State has also
been very active in identifying and controlling emissions from the oil
and gas industry. Wyoming has been ahead of the curve when it comes to
controlling emissions from this industry to protect health standards.
The EPA's recently finalized national oil and gas regulations to reduce
air pollutants from the oil and gas production industry were patterned
in large part after what Wyoming has been doing since the early 1990's.
Since 2005, the State has been spending more time and resources to
study and control emissions from natural gas production than any other
sector.
When it came time to address visibility impacts associated with the
oil and gas industry for the RHR, Wyoming completed the required
reasonable progress analysis. Wyoming also laid out reasons for why the
time was not right for requiring additional controls on the industry to
reduce visibility impairment, including lacking the very critical
information to be supplied by the WRAP inventory study. In spite of
Wyoming's diligent efforts, EPA disagrees with the State's reasoning
for not adopting reasonable progress controls for the industry during
the first planning period.
EPA has completely misunderstood the purpose of the collaborative
study to develop and implement a uniform procedure for estimating area
source emissions from oil and gas operations. Wyoming could not have
developed such a procedure on their own, and it continues to make no
sense for each state in the West to develop independent emission
inventories that cannot be compared to neighboring state inventories
for a regional effort. EPA should understand this better than any
individual state, since it relies on consistency in comprehensive
national inventories to develop sound national rules. While Wyoming
waits for the WRAP inventory study to be completed, it has not been
idle with respect to developing information on the oil and gas
industry. The State has invested huge resources in understanding
emissions from this industry and EPA's suggestion that the State ``just
develop the information'' shows a total lack of understanding of the
problem.
EPA's whole issue is about substituting its view regarding timing
in place of Wyoming's reasoned judgment. Wyoming is hopeful that as it
addresses ozone nonattainment it can also demonstrate the co-benefits
to improving visibility just as EPA has done in the East by developing
an ozone control strategy that also demonstrates adequate visibility
improvement. Wyoming's effort goes beyond the first planning period,
and is in accordance with the RHR. Wyoming respectfully requests that
EPA acknowledge that Wyoming participation in the regional inventory
development process satisfies reasonable progress for this first
planning period.
Response: We do commend the State for the work it is doing on
developing more comprehensive information on oil and gas emissions
although we disagree with this comment. As we stated in our
[[Page 5204]]
proposed notice, we disagree with the State's reasoning for not
adopting reasonable progress controls for oil and gas sources. If the
State determined that additional information on emission data from oil
and gas sources was needed to potentially control oil and gas sources,
the State should have developed the information in time for
incorporation into their SIP.
Comment: Wyoming's booming oil and gas industry has a significant
and growing impact on visibility in the State's national parks and
wilderness areas. Given the close proximity of some of Wyoming's
largest planned oil and gas fields to the Bridger and Fitzpatrick
wilderness areas--between just 10 and 200 miles--these magnificent
lands in western Wyoming suffer the greatest visibility impairment due
to oil and gas activities. The 4,399 additional approved wells in the
Pinedale Anticline Oil and Gas Exploration and Development Project
alone are projected to degrade visibility in the Bridger Wilderness by
up to 6.1 deciviews, and to cause impacts greater than 1.0 deciview on
45 days of each year. This impact is in addition to the impairment
caused by the existing 1,819 wells in the Pinedale Anticline area, and
the impacts from the numerous other existing and planned oil and gas
fields in the region.
Wyoming and EPA are obligated to reduce haze-causing emissions from
the State's oil and gas industry to achieve ``reasonable progress''
toward the national goal of eliminating human-caused visibility
impairment in Class I areas, 42 U.S.C. 7491(b)(2)(B), and doing so by a
target year of 2064, 40 CFR 51.308(d)(1)(i)(B), (ii). See also 42
U.S.C. 7491(b) (requiring ``measures as may be necessary to make
reasonable progress toward meeting the national [visibility] goal'').
Under Wyoming's Regional Haze SIP, natural visibility conditions would
not be reached in Wyoming's Bridger and Fitzpatrick Wilderness Areas
until 2165--more than 100 years past the 2064 goal set by EPA. Wyo.
309(g) SIP at 115. Although EPA's proposed FIP includes additional
measures that would hasten visibility improvement, EPA projects that
Wyoming Class I areas still will not achieve the URP necessary to
restore natural visibility by 2064. 78 FR 34788. Thus, EPA must
demonstrate the reasonableness of its decision not to require emissions
reductions from oil and gas activities that could make greater progress
toward restoring natural visibility. 40 CFR 51.308(d)(1)(ii).
Both Wyoming and EPA have failed to demonstrate that regulating
emissions from Wyoming oil and gas development activities is not
reasonable, in light of the facts that pollution-control technologies
are technologically feasible, cost effective, and would improve
significantly visibility across several affected Class I areas. EPA
properly ``disagree[s] with the State's reasoning for not adopting
reasonable progress controls for oil and gas sources.'' 78 FR 34765.
Specifically, EPA rejects the State's view that it needs more time to
collect information before it regulates the industry, stating ``[i]f
the State determined that additional information was needed to
potentially control oil and gas sources, the State should have
developed the information.'' Id. EPA also rejects Wyoming's claim that
it needs up to two years to develop necessary regulations, because
``[i]f regulations are needed to implement reasonable progress
controls, the State must develop them as part of the regional haze
SIP.'' See also id. at 34764 n.43. The Conservation Organizations agree
that Wyoming is not excused from regulatory requirements to commit
reasonable emissions reductions from the oil and gas industry in the
current planning period simply because Wyoming thinks more information
about oil and gas activity emissions would be desirable. See 78 FR
34765. As we pointed out in previous comments, ample information about
oil and gas industry emissions and their visibility impacts has already
been developed and published in numerous state and federal
environmental impact statements.
Response: EPA disagrees with the portions of this comment that take
issue with our proposed action. We acknowledge the comment's support
for our statement that Wyoming could not rely on the lack of data for
the State's determination for oil and gas sources. With respect to the
projected visibility impacts of future oil and gas production, we note
that the analysis cited by the commenter relied on a background ammonia
level of 1 ppb to determine visibility impacts on the Bridger
Wilderness. Elsewhere, we explain why we reconsidered use of a
background ammonia level of 2 ppb for modeling visibility impacts to
the Bridger Wilderness; as a result we remodeled using both a monitored
monthly varying concentration and an IWAQM default of 0.5 ppb for
background ammonia. Thus, the analysis cited by the commenter may
overstate visibility impacts. Furthermore, modeling of the visibility
impacts alone does not quantify the potential visibility benefits of
the controls the commenter supports.
The comment cites 40 CFR 51.308(d)(ii), which requires states (or
EPA in this instance) to demonstrate, when the RPGs fall short of the
URP, that the RPGs are reasonable and achieving the URP is
unreasonable. As we stated in our proposal, we found this to be the
case due to the results of the four-factor analyses along with
emissions from sources outside the WRAP domain. The commenter does not
take issue with the latter, and we explain elsewhere that we continue
to think that the controls considered by Wyoming are not so cost-
effective that it was necessarily unreasonable for Wyoming to require
them.
Comment: Although Wyoming's January 2011 SIP identified in
particular a need for the WRAP to complete its ``Phase III'' inventory
of Wyoming oil and gas emissions before requiring additional
regulations of the industry, that inventory was completed in November
2012. WRAP prepared technical memorandums specific to three areas in
Wyoming--the Powder River Basin, the Wind River Basin, and the Greater
Green River Basin--identifying both baseline emissions in 2006 and
projected emissions in 2015. Indeed, WRAP even has completed ``Phase
IV'' of its emissions inventory project, updating oil and gas industry
baseline emissions as of 2009 for specific regions, including all three
regions of Wyoming that were evaluated in Phase III. Thus, Wyoming has
no justification based on incomplete data for refusing to identify oil
and gas emissions control technology to satisfy reasonable progress
requirements. And there should be no reason for EPA to accept Wyoming's
invalid and outdated claim that more emissions information is needed
when that information was available for more than six months prior to
EPA's most recent Wyoming regional haze proposal.
Response: We disagree with this comment to the extent that it
argues we should not approve Wyoming's decision to not impose controls
on oil and gas sources. We did state in our proposal that the lack of
emissions data was not an appropriate justification for Wyoming's
decision to not impose controls on oil and gas sources. Instead, we
proposed to approve Wyoming's decision based on the cost of controls
and on the application of minor source BACT. The comment does not
identify anything in the November 2012 data that affects that rationale
and does not explain how emissions data would change the cost of
controls or the application of the SIP-approved minor source BACT
provisions. Thus the comment does not give a reason for us to change
our decision.
Comment: While EPA rejects Wyoming's rationale for refusing to
limit haze causing pollutants from this
[[Page 5205]]
booming industry, EPA provides insufficient rationale of its own to
justify the omission. EPA provides two reasons for proposing to accept
the State's plan not to require NOX emissions reductions
from Wyoming oil and gas sources. First, ``the most reasonable controls
are for compressor engines, which the State already controls through
its minor source BACT requirements.'' 78 FR 34765 & n.25 (citing
Wyoming Air Quality Standards and Regulations, Chapter 6, Section 2).
Second, ``while the costs of some controls are within the range of cost
effectiveness values Wyoming, other states, and we have considered as
reasonable in the BART context, they are not so low that we are
prepared to disapprove the State's conclusion in the reasonable
progress context.'' Id. at 34765. Neither contention is supportable.
EPA is wrong that compressor engine NOX emissions are
regulated through Wyoming's minor source BACT requirements. Wyoming's
minor source BACT guidelines for the oil and gas industry only regulate
VOC and hazardous air pollutants, not NOX. The guidelines
make no provisions for NOX controls at all. See State of
Wyoming, Oil and Gas Production Facilities Chapter 6, Section 2
Permitting Guidance (presenting controls that apply to VOC and
hazardous air pollutants, but not NOX).
Moreover, EPA's singular focus on compressor engines overlooks the
numerous other opportunities to significantly reduce haze-causing
emissions from oil and gas operations. As even Wyoming's analysis
demonstrates, cost-effective options are available to achieve high
control efficiency of NOX emissions from drill rig engines,
turbines, and process heaters. See 78 FR 34764 (Table 26).
Response: We disagree with this comment. Chapter 6, Sections 2 and
4, which are approved into the State's SIP, both require BACT for new
source compressor engines for regulated pollutants, which includes
NOX and VOC. These regulatory requirements should not be
confused with the State's oil and gas permitting guidance, which is not
part of the SIP. The State guidance document provides additional
compliance information for select sources of oil and gas VOC emissions,
such as dehydration units, pumps and tanks. There are many sources
which are regulated by the State's SIP and required to apply controls
that are not included in the oil and gas permitting guidance.
We also explained the reason we discussed compressor engines in
particular: the cost of controls for those sources was the most
reasonable. For other oil and gas sources, the costs were generally
higher. As we stated in our proposal, those costs were not so low that
EPA could find it necessarily unreasonable for the State to not have
adopted them. The comment gives us no reason to think otherwise.
Comment: EPA's justification that the costs of available controls
are reasonable, but not so low that EPA is willing to require them, is
both arbitrary and factually flawed. See 78 FR 34765 (``the costs of
some controls are within the range of cost effectiveness values
Wyoming, other states, and we have considered as reasonable in the BART
context''). EPA's justification is arbitrary because it has not
identified any objective threshold or rationale for reaching the
determination that costs, although low, are still too high to justify
modifying Wyoming's SIP determination.
Indeed, EPA rejected Wyoming's determination not to require
reasonable progress controls for Dave Johnston Units 1 and 2, where the
controls would cost approximately $1,000/ton of NOX removed.
See id. at 34788 (``Given predicted visibility improvement of
approximately 0.30 deciviews per unit at the most impacted Class I area
and the fact that Wyoming's RPGs will not meet the URP, we find that it
was unreasonable for the State to reject these very inexpensive
controls.''). EPA's statement that control technologies with similar--
and even lower--costs were not justified for the oil and gas industry
cannot be squared with this determination for Dave Johnston Units 1 and
2. See id. at 34765. As shown in Table 26 (of the proposed FIP),
emissions controls for compressor engines are available in the $16 to
$1,200/ton range. Id. at 34764. Enhanced NOX-control
technologies for drill rigs have cost-effectiveness values of $900 to
$1,000/ton. Id.
Controls for NOX emissions from turbines are very cost
effective at around $560/ton. Id. All of these costs are at or below
the costs that were deemed ``very reasonable'' at the Dave Johnston
power plant and which led to EPA rejecting the State's reasonable
progress control proposal. If finalized, EPA's contrary proposal for
the Wyoming oil and gas industry would be arbitrary.
Response: EPA disagrees with this comment. The comparison with the
costs of controls at Dave Johnston Units 1 and 2 is not apropos. First,
as explained elsewhere, certain oil and gas sources are subject to the
State's SIP-approved construction permit program, including the
requirement for minor source BACT. On the other hand, as explained
below in response to PacifiCorp's comments, PacifiCorp did not identify
(nor is EPA aware of) any NOX control measures for Dave
Johnston Units 1 and 2. Second, we did not propose to reject the
State's determination for these units solely on the basis of the cost-
effectiveness of controls. In addition, the State relied on
impermissible factors to disregard the results of its own four-factor
analysis. Third, to assist in determining whether the state's
determination for Dave Johnston Units 1 and 2 was reasonable or not, we
have quantified the visibility benefits of controls and decided that
the State's determination was not so unreasonable that we were prepared
to disapprove it. Neither the commenter nor EPA has equivalent data for
the oil and gas sources that the commenter mentions. The visibility
benefits of the commenter's suggested controls would of course vary
considerably depending on the location of the source and other factors,
and the data the commenter cites elsewhere regarding the bulk
visibility impacts of oil and gas development do not address visibility
benefits. Thus, the comparison with Dave Johnston gives no reason to
change our decision. Finally, the RHR does not require EPA to establish
a hard-and-fast dollar per ton threshold or other numeric criteria for
determining when a State's decision to not impose controls on
reasonable progress sources is unreasonable; rather all four factors
are to be considered under the reasonable progress provisions of the
RHR.
Comment: Control technologies to reduce oil and gas industry
NOX emissions are inexpensive and justified. Wyoming did not
identify the cost of available controls as an impediment to their
implementation, and Wyoming's own analysis demonstrated that cost-
effective controls to reduce oil and gas industry emissions are
available. See Wyo. 309(g) SIP at 123-26. In addition to Wyoming's
generic analysis, the Conservation Organizations have identified
available control technology. For example, the Bureau of Land
Management (BLM) recommended basic pollution-reduction strategies such
as replacing internal combustion engines for compressors with gas
turbines, installing SCR on drilling rig engines, using electric or
natural gas-powered drilling rigs, and centralizing production
facilities to reduce truck traffic. The cost-effectiveness of such
technologies is a reason for requiring them as reasonable progress
measures; costs are not a basis for allowing Wyoming to avoid
requirements to
[[Page 5206]]
reduce the large impact of the State's oil and gas industry on Class I-
area visibility.
Response: EPA disagrees with this comment. First, the commenter
incorrectly suggests that a ``generic'' analysis, rather than a source-
specific analysis, of the cost of controls for oil and gas sources
violates the RHR. In the reasonable progress context, the cost-of-
compliance factor can be interpreted to encompass either the cost of
compliance for individual sources or the cost of compliance for source
categories. The language of 40 CFR 51.308(d)(1)(i)(A), cited by the
commenter, does not explicitly require a source-specific analysis of
the costs of compliance, contrary to the commenter's assertion. With
respect to the control measures identified by BLM and referred to by
the commenter, neither the comment, nor the letter cited in the
comment, nor the records of decisions by the BLM cited by the letter,
provide any data on the cost-effectiveness of these measures. The
comment has no basis to describe the control measures identified by BLM
as cost-effective.
Comment: When a SIP fails to establish an emissions reduction
strategy that would achieve natural visibility conditions by 2064, as
is the case in Wyoming, the state must demonstrate that the underlying
``uniform rate of progress'' is ``not reasonable[,] and that the
progress goal adopted by the State is reasonable.'' 40 CFR
51.308(d)(1)(ii); see also EPA, Guidance for Setting Reasonable
Progress Goals Under the Regional Haze Program, at 2-3 (June 1, 2007)
(demonstration should ``identify and analyze the measures aimed at
achieving the uniform rate of progress and . . . determine whether
these measures are reasonable''). EPA proposes RPGs that leave
visibility impaired in Wyoming's affected Class I areas well beyond the
2064 goal set by EPA. See 78 FR 34788. In light of EPA's rejection of
every one of Wyoming's justifications for its conclusion that
reasonable progress controls on the oil and gas industry are not
reasonable, and EPA's lack of any valid rationale of its own to
conclude that such measures are not reasonable, the failure to adopt
any measures to reduce haze-causing emissions from the oil and gas
industry cannot be supported and must be changed in the final rule.
Response: EPA disagrees with this comment. In our proposal we
specifically stated our rationale for agreeing with Wyoming's
determination to not impose controls on oil and gas sources during this
planning period. We respond elsewhere to the commenter's disagreement
with that rationale. Because we are disapproving the State's RPGs, as
part of our FIP we are imposing RPGs that are consistent with the
controls in our FIP and the controls that we are approving in the
State's SIP. We stated in our proposal that it was reasonable for the
RPGs to fall short of the URP based not only on our consideration of
the four statutory reasonable progress factors, but also based on
emissions from sources outside the WRAP domain, which the commenter
does not take issue with.
Comment: EPA proposes to approve Wyoming's reasonable progress
determinations for oil and gas sources. 78 FR 34765. However, EPA
states that it ``disagree[s] with the State's reasoning for not
adopting reasonable progress controls for oil and gas sources.'' Id.
Wyoming explained in its SIP that it required additional information
before it can determine whether and to what extent additional controls
are necessary for oil and gas sources. Id. EPA thinks Wyoming should
have obtained the additional information before submitting its SIP,
though, EPA does not hold itself to this same standard. Nonetheless,
EPA has previously recognized Wyoming's expertise and leadership in
regulating the air quality impacts of oil and gas development. 76 FR
52738, 52757 (Aug. 23, 2011). In light of Wyoming's leadership in
regulating air pollution from oil and gas development, EPA should
approve Wyoming's reasonable progress determination for oil and gas
sources.
Response: EPA disagrees with this comment. We are approving
Wyoming's reasonable progress determination for oil and gas sources,
although not on the State's basis. The notice cited in the comment
relates to EPA's development of new source performance standards for
oil and gas sources, which is not relevant to this action. As we
explained in our proposal and elsewhere in these responses, the RHR
sets certain requirements for reasonable progress for the first
planning period and does not provide for deferring those requirements
to later planning periods; thus, the State's basis for its reasonable
progress determination for oil and gas sources is invalid. Finally,
while we did not re-run the WRAP modeling to quantify our RPGs, the
State did not modify its RPGs or re-run the WRAP modeling to reflect
the controls the State selected.
Comment: We received numerous comments urging EPA to require
pollution controls on the oil and gas industry.
Response: There are a number of provisions in the CAA that
potentially apply to oil and gas sources. With respect to the
requirements of the RHR for those sources, we have evaluated Wyoming's
submittal and we are approving it.
b. Dave Johnston Units 1 and 2
Comment: Wyoming did not evaluate the effectiveness of the
LNB+OFA+SCR option. Instead, Wyoming assumed addition of SCR to these
currently uncontrolled EGUs would only reduce NOX emissions
by 79% down to 0.12 lb/MMBtu on an annual average basis, although it is
generally assumed that SCR can reduce NOX emissions by 90%
or down to 0.05 lb/MMBtu (or lower). Wyoming has not provided any
documentation or justification to support the higher emission rates
used in its analyses. Such an approach at Johnston adversely biases the
cost-benefit analysis and is inconsistent with other EPA analyses.
Response: The commenter has incorrectly assumed that a 90% control
efficiency can be achieved in all SCR applications regardless of the
input NOX emission rate or other parameters. In addition, we
note that the emission rate analyzed by Wyoming, 0.07 lb/MMBtu, was on
a 30-day rolling average basis, not an annual basis. Regardless, we
agree that SCR can in most cases achieve a performance rate of 0.05 lb/
MMBtu on an annual basis. (See section IV.C.4 of this rulemaking for
more information on the control effectiveness of SCR.) We have revised
the SCR costs for Dave Johnston Units 1 and 2 accordingly. However, as
explained elsewhere, the revised costs for SCR have not led us to
change our determination that the State was reasonable in not selecting
SCR for Units 1 and 2.
Comment: Wyoming has assumed that Dave Johnston Unit 1 and Unit 2
emitted at 0.57 lb/MMBtu on an annual basis and used this as the
baseline condition from which to calculate the control efficiency it
used for each control option. However, our review of CAMD data back to
2000 shows that the highest annual NOX emission rate for
Unit 1 was 0.474 lb/MMBtu (2002) and 0.460 lb/MMBtu for Unit 2 (2006).
For the 2001-2003 baseline period, annual NOX emissions were
0.46 and 0.44 lb/MMBtu for Johnston Unit 1 and Unit 2, respectively.
Thus, Wyoming's proposal to reduce NOX to 0.20 lb/MMBtu with
LNB+OFA represents a 56% reduction instead of 65% assumed by Wyoming.
Response: In our revised cost analysis, we used baseline emissions
for Dave Johnston Units 1 and 2 that reflect annual average emissions
between 2001 and 2003, as found in the CAMD emissions system. These
baseline rates
[[Page 5207]]
are 0.45 lb/MMbtu and 0.41 lb/MMBtu, respectively. This corresponds to
a 56.0% and 54.6% reduction, respectively.\238\ Therefore, our revised
cost analysis has addressed the concern raised by the commenter. As
explained elsewhere, our revised costs have been taken into account,
along with our revised visibility modeling, in our decision to approve
the State's determination to not impose controls at Units 1 and 2.
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\238\ Staudt memo, Tables 2 and 3.
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Comment: The Conservation Organizations agree with EPA that
reasonable progress controls for NOX emissions are needed
for Dave Johnston Units 1 and 2. EPA correctly found that it was
unreasonable for Wyoming to reject cost effective NOX
controls that would improve visibility. EPA proposes to require only
LNBs/OFA to achieve a NOX emission limit of 0.20 lb/MMBtu
(30-day rolling average). While we commend EPA for proposing a FIP to
reduce NOX emissions from Dave Johnston Units 1 and 2, we
urge EPA to require SCR plus LNBs/OFA to meet a NOX emission
limit of 0.05 lb/MMBtu to achieve reasonable progress. Although EPA
concluded that the cost of SCR is not justified by the projected
visibility improvement, EPA's analysis unreasonably assumed that SCR
would only achieve a NOX emission rate of 0.12 lb/MMBtu,
even though an emission rate of 0.05 lb/MMBtu is readily achievable.
Correcting for this error, it appears that SCR at Dave Johnston Units 1
and 2 is very cost effective at $2,001 and $1,987/ton of NOX
removed, respectively. Accordingly, EPA should reconsider requiring SCR
at Dave Johnston Units 1 and 2 to meet reasonable progress
requirements.
Response: As discussed in our proposed rulemaking, we have revised
the SCR cost analysis for Dave Johnston Units 1 and 2 to reflect the
installation of LNB and OFA. However, our revised cost effectiveness
values of $3,496/ton and $3,672/ton, respectively, are much higher than
those suggested by the commenter. We also note that the incremental
costs for this option are high, at $9,798 and $9,588 per ton,
respectively. In light of this, and our revised modeling results, we do
not find it unreasonable for the State to not have imposed SCR on these
units.
Comment: EPA's conclusion that the addition of SCR is not justified
due to the ``small incremental visibility improvement'' is based upon a
flawed visibility analysis that over-values the addition of LNB + OFA
and under-values the addition of SCR. Furthermore, the degree of
visibility improvement is not one of the four statutory factors to be
considered under the reasonable progress provisions of the RHR.
Incremental visibility improvement is not mentioned anywhere in the
reasonable progress provisions or BART Guidelines and EPA cannot create
a new criterion for the sole purpose of eliminating a control option
that is reasonably cost-effective and would yield a significant
visibility improvement.
Response: As discussed elsewhere in this rulemaking, we have
corrected the modeling analysis for Dave Johnston Units 1 and 2, and
the commenter's concerns regarding our methodology have been addressed.
Our revised modeling analysis shows that the visibility improvement
associated with SCR with LNB and OFA at Units 1 and 2 is 0.18 deciviews
and 0.18 deciviews, respectively. The visibility improvement associated
with LNB and OFA is 0.12 deciviews and 0.11 deciviews, respectively. We
continue to find that the additional visibility improvement is not
significant enough to warrant selection of SCR with LNB and OFA for
these reasonable progress sources. As discussed earlier, we also find
that the visibility improvement from LNBs and OFA does not justify us
requiring reasonable progress controls on these two units. While it is
true that incremental visibility improvement is not among the four
statutory reasonable progress factors, the RHR does not prohibit EPA
from assessing visibility improvement, in addition to the four
statutory reasonable progress factors, when considering controls at
potentially affected sources. We did not create a new criterion for the
sole purpose of eliminating SCR at Dave Johnston Units 1 and 2;
instead, we think it appropriate to consider visibility improvement
when assessing control options for reasonable progress, especially when
taking into account the purposes of the RHR. In comparing control
options and selecting one, it is appropriate to compare the visibility
improvement (that is, to compute the incremental visibility
improvement) for each option.
Comment: EPA is proposing that the FIP NOX BART for Dave
Johnston Units 1 and 2 is LNBs with OFA at an emission limit of 0.22
lb/MMBtu (30-day rolling average). EPA provided no reason for rejecting
addition of SCR even though: (1) Cost/ton was $3,300-$3,400, which is
less than the $3,900/ton accepted at Laramie River Unit 3; (2)
Visibility at the most-impacted Class I area would improve by more than
0.4 deciview (which is greater than the 0.3 deciview improvement for
EPA's proposal; (3) Cumulative visibility improvement would exceed 0.6
deciviews (versus EPA's proposed 0.43 deciview improvement for Dave
Johnston Unit 2 at Wind Cave and Badlands); (4) Cost-effectiveness is
$15 million/deciview at Wind Cave (versus $27,798,246/deciview at
Badlands due to application of SCR to Laramie River Unit 3); (5)
Cumulative cost-effectiveness is less than $10 million/deciview (versus
$10,140,825/cumulative deciview due to application of SCR to Laramie
River Unit 2.)
We believe that SCR is Reasonable Progress for Dave Johnston Units
1 and 2. Under the EPA proposal, Dave Johnston Units 1 and 2 would each
contribute over 0.9 deciview impairment at Wind Cave National Park (and
0.7 deciviews at Badlands National Park). With the addition of SCR,
impairment would drop to less than 0.5 deciviews for each unit.
Response: We disagree with this comment. We have responded in
detail to the use of a $/deciview metric in section V.D.1.b of this
final rulemaking action. In addition, as stated above, our revised
modeling analysis shows that the visibility improvement associated with
SCR with LNB and OFA is 0.18 deciviews and 0.18 deciviews,
respectively. By contrast, the visibility improvement associated with
LNB and OFA, is 0.12 deciviews and 0.11 deciviews, respectively. We
continue to find that the additional visibility improvement is not
significant enough to warrant selection of SCR with LNB and OFA for
these reasonable progress sources, and as discussed earlier in our
response to comments, we do not find the visibility improvement, when
considered with the other reasonable progress factors, from LNBs and
OFA warrants the implementation of reasonable progress controls. In
addition, as we discuss above, the revised incremental costs for SCR
that we present above are sufficiently high for us to conclude that it
is reasonable to not impose SCR on Dave Johnston Units 1 and 2.
Comment: EPA acknowledged that, for a reasonable progress analysis,
only four factors must be analyzed. Indeed, the CAA clearly requires
only four factors be analyzed. 42 U.S.C. 7491(g)(1). EPA employed the
four-factor reasonable progress analysis for the other two Wyoming
reasonable progress sources: oil and gas sources and the Mountain
Cement Company plant. EPA has approved other regional haze SIPs where
the state employed this same four-factor analysis, including Nevada.
For both the oil and gas sources and the Mountain Cement Company
[[Page 5208]]
plant, EPA disagreed with Wyoming's reasonable progress analysis and
found ``cost effective'' NOX controls could be employed, but
EPA did not require those NOX controls because the costs
were ``not so low that we are prepared to disapprove the State's
conclusion in the reasonable progress context.'' If EPA found the
NOX controls ``cost effective'', then PacifiCorp is unclear
what additional cost analysis was performed, or what the statutory or
regulatory basis for EPA's additional cost analysis may be. EPA does
not differentiate PacifiCorp's Dave Johnston Units 1 and 2 from the oil
and gas sources or the Mountain Cement Company plant.
Also, EPA has approved other reasonable progress SIPs where the
state is not meeting the URP, but has determined that no reasonable
progress controls are required for the initial planning period. (See 77
FR 30248, 30256-30257; SIP Approval for Idaho). Here, EPA admitted that
Wyoming ``provided a four factor analyses that adequately evaluated the
required factors'' for Dave Johnston Units 1 and 2, but then
arbitrarily concluded ``it is also appropriate for this facility to
consider a fifth factor for evaluating potential reasonable progress
control options--the degree of visibility improvement that may
reasonably be anticipated from the use of reasonable progress
controls.''
EPA justified its decision by citing to EPA guidance on states
setting reasonable progress goals. However, the referenced guidance
does not support EPA's position for several reasons:
The guidance concedes it is ``merely guidance and that
States or the . . . [EPA] may elect to follow or deviate from this
guidance, as appropriate.'' EPA cannot find Wyoming acted
``unreasonably'' when it chose not to apply discretionary guidance.
The guidance identifies several factors that EPA did not
include in its proposed regional haze FIP, such as the ``control
measures and associated emission reductions that are expected to result
from compliance with existing rules.'' EPA cannot criticize Wyoming for
not following the guidance when EPA itself chose not to apply part of
the same guidance in the EPA regional haze FIP.
The guidance suggests that air quality models be used to
estimate ``the improvement in visibility that would result from the
implementation of the control measures you have found to be reasonable
and compare this to the uniform rate of progress.'' Here, EPA has no
``modeling results'' demonstrating the alleged improvement in
visibility from the suggested NOX controls and the impact on
the URP.
The States, not EPA, are to determine the
``reasonableness'' of RPGs and are given flexibility to do so.
The guidance clearly indicates that a state must support
its RPGs ``based on the statutory factors,'' which EPA admits Wyoming
did.
Finally, the guidance explains that no additional
reasonable progress controls may be needed for the first planning
period.
Response: EPA disagrees with this comment. With respect to the
reasonable progress determination for the Mountain Cement facility, the
cost effectiveness of potential controls is generally higher than the
controls we proposed for Dave Johnston Units 1 and 2. As we stated in
our proposal, although the costs for potential controls for the
Mountain Cement facility might be considered reasonable in the BART
context, in the reasonable progress context those costs were not so low
that we were prepared to disapprove the State's determination to not
impose controls. That was not the case for Dave Johnston Units 1 and 2,
for which combustion controls were significantly more cost-effective.
Similar reasoning applies to the cost-effectiveness of controls for the
oil and gas sources; in addition, as we noted in the proposal, Wyoming
generally applies minor source BACT to these sources.
As a result, EPA determined that we should perform visibility
modeling to assess the visibility benefits of controls on Dave Johnston
Units 1 and 2. As explained elsewhere, we considered it appropriate to
assess, in addition to the four statutory reasonable progress factors,
the visibility improvement from potential controls at these units,
particularly in light of the purposes of the RHR. In this instance, the
revised visibility modeling has confirmed that the State's decision to
not impose controls on Dave Johnston Units 1 and 2 (although not the
State's rationale) was not so unreasonable that EPA is compelled to
disapprove it.
EPA also disagrees that EPA's proposal was inconsistent with the
cited notice proposing action on the Idaho Regional Haze SIP. In that
notice, EPA stated, ``EPA agrees with Idaho's conclusion that
additional controls of non-BART point sources for reasonable progress
purposes are not reasonable at this time, because even though there are
cost effective controls identified, visibility improvement is
anticipated to be relatively small.'' (77 FR 30248, 30256, May 22,
2012) (emphasis added). To derive that conclusion, EPA examined the
modeled visibility impacts for the BART eligible sources and noted
that, in Idaho's case, the sources with a Q/d of less than 26 had
visibility impacts of less than 0.5 deciviews. EPA conservatively
inferred from this that other potentially affected sources in Idaho
with a Q/d of less than 20 would likely also have visibility impacts of
less than 0.5 deciviews. In contrast, our original proposal showed
modeled benefits at each unit of 0.3 deciviews from combustion
controls. As a result, we reject the comparison with the notice
proposing action on the Idaho Regional Haze SIP. Nonetheless, based on
our revised modeling we have reconsidered our proposed determination to
require LNBs and OFA on these two units, and now do not find the
State's decision to not impose controls to be unreasonable.
Furthermore, we are not disapproving the State's determination of
which sources should be considered potentially affected sources.
Wyoming reasonably used a Q/d threshold of 10 for determining the set
of potentially affected sources, and the State selected (among others)
Dave Johnston Units 1 and 2. That Idaho used a different threshold does
not show that Wyoming's choice was unreasonable. However, even if EPA
in the first instance was selecting potentially affected sources, we
might also consider it reasonable to select Dave Johnston 1 and 2 based
on a Q/d threshold.
We disagree that we cited our reasonable progress guidance as part
or whole of our basis for proposing to disapprove the State's
reasonable progress determination for Dave Johnston Units 1 and 2.
Instead, we briefly cited the guidance for the unremarkable proposition
that the State must at a minimum consider the four statutory reasonable
progress factors but could also take into account other relevant
factors. Our proposed disapproval was not based on that proposition,
but was based on the State's inadequately supported determination to
not impose controls, which relied on impermissible factors. Although
the commenter argues that it is the State, and not EPA, that should
determine reasonable progress, as explained above we are required to
evaluate the State's reasonable progress determinations. 40 CFR
51.308(d)(1)(iii).
We disagree with the commenter's other statements regarding the
guidance. While the State did assess the four statutory reasonable
progress factors for Dave Johnston Units 1 and 2, the guidance does not
suggest that a state may ignore the results of that assessment for
impermissible reasons such as a claimed lack of authority. The
[[Page 5209]]
guidance also does not suggest that a state may per se choose to impose
no reasonable progress controls regardless of the state's assessment of
the four statutory factors.
Guidance aside, both the Act and the RHR explicitly require the
state to consider the four factors for potentially affected sources.
CAA section 169A(g)(1) (``shall be taken into consideration''); 40 CFR
51.308(d)(1)(i)(A). Assessing the four factors but ignoring the results
of that assessment for invalid reasons such as lack of authority to
impose controls does not amount to considering the factors and violates
the explicit requirements of the Act and the RHR.
With respect to control measures expected to result from compliance
with existing rules, the commenter did not identify any such
NOX control measures for Dave Johnston Units 1 and 2, nor
are we aware of any. Finally, we did independently run CALPUFF to model
the visibility improvement from potential controls at Dave Johnston
Units 1 and 2 and it is part of the basis for our final decision.
F. General Comments
1. Replacement of FIP Elements With SIP
Comment: EPA has proposed to disapprove the monitoring,
recordkeeping, reporting, and RAVI portions of Wyoming's SIP. 78 FR
34788. Wyoming acknowledges these deficiencies in its SIP and commits
to making the necessary revisions. However, Wyoming will revise its SIP
in a manner that comports with statutory and regulatory processes.
Unlike EPA, Wyoming will not shortcut legal processes designed to
ensure FLM consultation and public participation to meet an arbitrary
deadline EPA has established with special interest groups in litigation
to which Wyoming was not a party. Such arbitrary deadlines defeat the
cooperative federalism Congress intended to guide CAA implementation by
needlessly expediting the process, tying EPA's hands, and precluding
the State from an opportunity to revise its SIP. In this context, EPA's
promise--to ``propose approval of a SIP revision as expeditiously as
practicable if the State submits such a revision and the revision
matches the terms of our proposed FIP,'' id. 34738--rings hollow.
Response: We appreciated the State's willingness to make the SIP
revisions necessary to correct the deficiencies with the monitoring,
recordkeeping, reporting, and RAVI requirements. Once EPA receives the
SIP revisions from the State, EPA will work as expeditiously as
practicable to review such revisions and approve the State's revisions
if they meet the terms of our FIP. We have responded to other comments
elsewhere in this document.
2. Public Comment
Comment: DEQ and Governor Mead requested that EPA defer its hearing
until sixty days after the date EPA first released its proposal, with
an additional thirty days of comment after the hearing. See, e.g.,
Letter from Todd Parfitt, Director, DEQ, to Shaun McGrath, Region 8
Administrator, EPA (June 14, 2013). Although EPA agreed to hold two
additional public hearings and provide an additional thirty days for
public comment, EPA did not provide the time for public participation
that Wyoming requested, evidently because EPA wanted to meet the
deadline for final action it established with the special interest
groups. Thus, while EPA did not hesitate to extend that deadline on
multiple occasions when it benefitted EPA and the special interest
groups, EPA refused to provide the additional time Wyoming requested
for the benefit of the State.
We also received comments from other parties that we should extend
the public comment period so that there is more time to review and
comment on our action. Some commenters specifically requested a 60-day
extension of the comment period. One commenter noted that if the
driving force for the short timeframe in this instance is a consent
decree to which the EPA is a party, that no agreement between an agency
and any interested party, whether as part of litigation or not, should
or can modify requirements of law for a meaningful opportunity for
public comment.
Response: EPA took several steps to provide the opportunity for
meaningful public comment. In addition to the initial 60-day public
comment period, we extended the public comment period from August 9,
2013, until August 26, 2013. In doing so, we took into consideration
how an extension might affect our ability to consider comments received
on the proposed action and still comply with the terms of the consent
decree deadline,\239\ which at the time required our final action
signed by the Administrator on or before November 21, 2013.
Additionally, we could not extend the comment period any further and
still have time to respond to the immense amount of public comments we
anticipated receiving. As the commenter notes, EPA also added two
public hearings and we received substantial comments at these
additional hearings. We find that the comment period provided for the
Wyoming Regional Haze SIP and FIP exceeds CAA requirements and is
reasonable and consistent with what the Agency has provided on other
FIP and SIP actions. For example, EPA provided a 60-day comment period
for both the Montana and North Dakota regional haze actions (see 77 FR
23988 and 76 FR 58570, respectively.) In addition, in our first
proposal on Wyoming regional haze (77 FR 33022), we provided a 60-day
comment period with no objections from interested parties.
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\239\ WildEarth Guardians v. McCarthy, Case No. 1:11-cv-0001-
CJA-MEH.
---------------------------------------------------------------------------
Finally, the State and impacted sources have had many years to
prepare and submit an approvable SIP to EPA. As detailed in the Docket
for this action, the State received numerous detailed comment letters
from EPA on many issues and also participated in meetings with EPA.
Indeed, the fact that the State was able to prepare an extensive 33-
page document and provide extensive comments at the various public
hearings, all within the allotted time period, supports EPA's
contention that the 77-day time period for this proposed rulemaking was
reasonable.\240\
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\240\ In fact, the State received the proposed notice on May 28,
2013, two business days after the proposal was signed, and the
proposed notice was posted on the Region's Internet site on May 28,
2013, well in advance of the Federal Register publication on June
10, 2013.
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3. Economic Concerns
Comment: We received numerous comments that the FIP will cost
anywhere from an additional $300 million to $1 billion more than the
State's SIP, but provide no perceptible improvement in visibility when
compared with the SIP. We received numerous comments that EPA's FIP
would lead to higher electricity costs to consumers and job losses at a
time when the economy and people cannot afford an additional burden.
Response: We disagree with these comments. We have addressed the
issue of perceptible visibility improvement in section V.C.5 of this
final rulemaking. In addition, it is not EPA's intention to endanger
the economic viability of or to place an undue burden on PacifiCorp or
Basin Electric's customers. EPA has considered the comments on these
issues very carefully. Regarding the legal basis for our decision,
neither the CAA nor the RHR requires states or EPA to consider the
affordability of controls or ratepayer impacts as part of a BART
analysis. Rather, the CAA and RHR require consideration of the
following factors, which as detailed elsewhere in
[[Page 5210]]
our notice, we have fully considered: ``The costs of compliance, the
energy and non-air quality environmental impacts of compliance, any
existing pollution control technology in use at the source, the
remaining useful life of the source, and the degree of improvement in
visibility which may reasonably be anticipated to result from the use
of such technology.''
Comment: One commenter noted that visitors to Wyoming's parks
notice when the air is dirty, which can have a direct impact on
tourism, the second largest business in the State. According to
Wyoming's Office of Tourism, the travel and tourism industry in Wyoming
creates 30,000 jobs and generates $730 million in employment earnings
and $2.8 billion in travel expenditures annually. Over 3.5 million
people visit Yellowstone National Park each year. The Commenter also
indicated that the proposed plan will also reduce health care costs in
the State. Combined, coal plants in Wyoming emit over 60,000 tons of
NOX pollution and almost 65,000 tons of SO2
pollution annually. The Clean Air Task Force estimates that coal plant
pollution in the State results in over $850 million in preventable
health care costs.
Response: We acknowledge the commenter's points.
Comment: We received a comment that EPA failed to calculate the
costs of the proposed rule that will be passed on to residential and
business customers.
Response: Explained elsewhere in this document, we have taken these
costs into consideration.
Comment: We received numerous comments that EPA's action could have
the potential to shift the energy balance in favor of gas, rather than
coal, and that this shift may force utilities to convert their power
plants from coal to natural gas. Commenters expressed particular
concern over the potential conversion of Naughton Unit 3, and possibly
Naughton Units 1 and 2. Commenters expressed concern over the potential
impacts natural gas conversion could have on local economies.
Response: As stated above, the CAA and RHR require consideration of
the five statutory factors. Based on our consideration of these
factors, EPA determined the appropriate emission limit for BART for
each unit. Sources have the choice of how to meet that limit, including
conversion to natural gas. EPA's action does not require any source to
convert to natural gas, as all of the requirements in our FIP can be
met with combustion and post-combustion control technology.
Comment: One commenter stated that coal-fired plants in Wyoming
have installed over one billion dollars in additional air quality
controls and that, according to EPA standards, Wyoming has better
visibility than virtually any other state in the country. Therefore, it
seems unreasonable, illogical and, frankly, irrational that the EPA
would demand Wyoming businesses and homeowners foot the bill for
another one billion dollars in emission controls that have little
probability of improving the quality of lives or the livelihoods of our
citizens and, in fact, has a great potential to harm our people and our
state.
Response: EPA disagrees with this comment. EPA carefully considered
the five statutory factors and determined that there are additional,
cost-effective controls that will result in significant visibility
improvement in Wyoming's Class I areas, and that these controls
represent BART.
Comment: One commenter was concerned that the investments mandated
under the FIP will have significant adverse impacts on the quality and
reliability of service provided to Wyoming ratepayers. The SIP is a
well vetted plan by the State and its stakeholders that, in association
with other regulatory requirements such as the construction authority
process, assures that Wyoming utilities will be able to comply with its
requirements with the least amount of impact to customers. The FIP, on
the other hand, with its more stringent control requirements and
accelerated compliance deadlines, will assure not only that compliance
is needlessly expensive, but that it is also rushed, that scheduled
outages cannot be timed to minimize the cost of replacement power, and
that third party vendors will have free reign in determining how much a
particular project costs. To the extent that schedules cannot be met,
non-compliant plants will be forced out of service until the work is
done. Such outages will necessitate the purchase of replacement power
in the market and will result in diminishing system reserves, all of
which will jeopardize system reliability and increase costs for
ratepayers.
Response: We appreciate the commenter's concerns, but note that the
commenter has provided no data to support these assertions.
Comment: The companies working with Wyoming have scheduled shutdown
and installation on a schedule that will allow them to maintain service
to their customers. The new timeline demanded in the re-proposal would
threaten both service interruptions and an increased risk of having to
spot purchase energy which would be an additional increase of costs to
residential, business, manufacturing, and agricultural customers.
Response: We appreciate the commenter's concerns, but note that the
commenter has provided no data to support these assertions.
Additionally, CAA section 169A(b)(2)(A) requires subject-to-BART
sources to install BART and comply with any applicable emission limits
``as expeditiously as practicable.'' The Act defines this term to mean
``as expeditiously as practicable but in no event later than five years
after . . . the date of promulgation.'' CAA section 169A(g)(4).
Consequently, the final rule appropriately provides that the BART units
must comply with the emission limits as expeditiously as practicable
but in no event later than five years after the date of promulgation of
the final rulemaking.
4. National Ambient Air Quality Standards (NAAQS)
Comment: The EPA is duty-bound to ensure that the proposed SIP does
not interfere with attainment and maintenance of the NAAQS, in
accordance with section 110(l) of the CAA. Thus, the EPA must ensure
that the proposed SIP and the proposed FIP adequately limit air
pollution in order to safeguard public health.
In this case, we are concerned that in proposing to approve
portions of Wyoming's regional haze plan, the EPA has not demonstrated
that the proposal adequately safeguards the 2008 8-hour ozone NAAQS
(see 40 CFR 50.15), the newly promulgated 1-hour nitrogen dioxide
(``NO2'') NAAQS (see 40 CFR 50.11(b)), the newly promulgated
1-hour SO2 NAAQS (see 40 CFR 50.17), the 2006 24-hour
PM2.5 NAAQS (see 40 CFR 50.13), and the 2012 annual
PM2.5 NAAQS (see 78 FR 3086 (Jan. 15, 2013)).
We are particularly concerned that the EPA overlooked its 110(l)
obligations under the CAA given that, although the Proposed Rule may
lead to emission reductions, no analysis or assessment has been
prepared to demonstrate that even after these emission reductions, the
recently promulgated NAAQS will be met. In this case, we are
particularly concerned that the recently promulgated 1-hour
NO2 and SO2 NAAQS could be jeopardized, as well
as the recently promulgated 2012 PM2.5 annual NAAQS. Indeed,
many, if not most, of the proposed emission rates are based on 30-day
rolling averages. There is no indication that meeting emission rates on
a 30-day rolling average will ensure that 1-hour NAAQS will be
sufficiently protected. Indeed, a source could comply with a 30-day
rolling average limit, yet still emit enough pollution on
[[Page 5211]]
an hourly basis to cause or contribute to violations of the NAAQS,
thereby interfering with attainment or maintenance. Further, there has
been no analysis at all as to whether the recently promulgated
revisions to the annual PM2.5 NAAQS will be protected.
In this case, the EPA must either disapprove the Wyoming SIP over
the State's failure to perform a 110(l) analysis or prepare its own
110(l) analysis to demonstrate that the SIP will not interfere with
attainment or maintenance of the NAAQS. Furthermore, the EPA must
demonstrate that its FIP will not interfere with attainment or
maintenance of the NAAQS. The EPA has not done so, rendering its
proposed rule substantively flawed.
Response: CAA section 110(l) provides that EPA ``shall not approve
a revision of a plan if the revision would interfere with any
applicable requirement concerning attainment and reasonable further
progress . . ., or any other applicable requirement of'' the CAA. The
commenter has not provided any evidence that the Wyoming Regional Haze
SIP will interfere with any applicable requirement concerning
attainment and reasonable progress or any other applicable requirement
of the CAA, or that further analysis under 110(l) is necessary. To the
contrary, the commenter acknowledges that the Regional Haze SIP
revision will lead to emission reductions.
The commenter asserts that it is not enough that the SIP will lead
to emission reductions and that EPA must determine that the SIP will
ensure the NAAQS are met. We disagree. The CAA and EPA's regulations
require regional haze SIPs to address visibility impairment in
mandatory Class I areas; attainment of the NAAQS is provided for
through a separate SIP process. It is EPA's consistent interpretation
of section 110(l) that a SIP does not interfere with attainment and
maintenance of the NAAQS if the SIP at least preserves the status quo
air quality by not relaxing or removing any existing emissions
limitation or other SIP requirements. EPA does not interpret section
110(l) to require a full attainment or maintenance demonstration for
each NAAQS for every SIP revision. See, e.g., Kentucky Resources
Council, Inc., v. EPA, 467 F.3d 986 (6th Cir. 2006); see also, 61 FR
16050, 16051 (April 11, 1996) (actions on which the Kentucky Resources
Council case were based).
Thus, in this action, we need not determine whether a 30-day limit
is adequate to protect a shorter-term NAAQS because the regional haze
SIP is not required to ensure attainment of the NAAQS. The fact that
the regional haze SIP specifies 30-day limits will not preclude Wyoming
from adopting limits with a shorter averaging time, if at some future
date such limits are found to be necessary and required by the CAA to
protect the NAAQS.
5. Other
Comment: We received over 250 comments in a general mass mailer
campaign in support of our action. We received over 220 mass mailer
comments on behalf of National Parks Conservation Association in
support of our action. We also received numerous general comments from
individuals and organizations in support of our action.
Response: We acknowledge the commenters' support of our proposed
action.
Comment: We received over 850 mass mailer comments opposed to our
action. We also received numerous general comments from individuals and
organizations in opposition to our action.
Response: We note the commenters' opposition to our proposed
action.
Comment: We received numerous general comments in opposition to our
action that stated that the State's plan was good enough, that it would
achieve appropriate emission reductions, and that it represented a
balanced approach.
Response: We note the commenters' opposition to our proposed
action.
Comment: We received numerous general comments in opposition to our
FIP that stated that the visibility in Wyoming is not hazy and that
Wyoming has some of the best air quality in the country.
Response: We note the commenters' general qualitative observations,
but note that the commenters did not provide any quantitative
information to substantiate their comment.
Comment: We received numerous comments that we should approve
Wyoming's SIP because it represents collaboration between the State,
industry, local governments, and the public.
Response: We note the commenters' points, but as stated earlier,
EPA can only approve a state's SIP if it meets the requirements of the
CAA and EPA's implementing regulations.
Comment: We received numerous comments that EPA's FIP will only
reduce NOX by 2,900 tpy more than the Wyoming's SIP, which
reduces NOX by 63,000 tpy. Other commenters went on to say
that EPA's FIP will basically achieve the same emission reductions the
State's SIP would by 2022.
Response: We disagree with this comment. EPA's calculations show
that our proposed FIP will result in approximately 17,000 tpy more
NOX reductions than the State's SIP, through 2022 and
beyond.
Comment: We received numerous comments that the proposed FIP, along
with other EPA regulations, are in support of EPA's hidden agenda to
kill the coal industry and shut down coal-fired power plants.
Response: As stated earlier, EPA's proposed action was based on its
careful consideration of the five statutory factors in the CAA and
related statutory and regulatory requirements.
Comment: We received numerous comments that the State's SIP was
created through coordination with PacifiCorp and other Wyoming
industries and that it is based on sound science that complies with the
CAA and provides a balance between achieving compliance with the RHR
while ensuring reliable, affordable electricity.
Response: We note the commenters' points, but as stated earlier,
EPA can only approve a state's SIP if it meets the requirements of the
CAA and EPA's implementing regulations.
Comment: We received a comment that it is generally more hazy now
than it was ten years ago and that the commenter was supportive of
reducing haze.
Response: We note the commenter's support.
Comment: We received a comment that provided data that showed
voters in Wyoming were supportive of continued implementation of the
CAA and environmental protections for our environment. The commenter
went on to say that the majority of voters thought environmental
protection and a good economy were compatible and encouraged EPA to
finalize its proposed action. The commenter urged EPA to ignore
negative media attention its action has drawn, stating that the
negative publicity was being driven by economic interests.
Response: We note the commenter's support of our proposed rule.
Comment: EPA has applied selective comment response to the
development of its re-proposal and the public comment process, which is
inappropriate. EPA's process has lacked transparency, particularly to
the State. EPA has not acknowledged the Governor's comments submitted
last year. The EPA has not acknowledged the DEQ's comments submitted
last year. DEQ was not consulted in the re-proposal process. It would
appear that EPA only considered select comments that support its
predetermined agenda.
[[Page 5212]]
Response: Consistent with our statutory obligations, we have
evaluated all written and oral comments on the proposal rulemaking
(placing all the comments received in the docket for this action at
www.regulations.gov); determined whether any revisions to the proposed
rule are warranted; and prepared the final rulemaking and supporting
information. The final rulemaking decisions are accompanied by the
bases for the decisions, explanations of major changes from the
proposals, and a response to each of the significant comments submitted
in written or oral presentations during the comment period, which
includes responses to such comments submitted by the Governor and DEQ.
Comment: For years, Wyoming has pursued developing a collaborative
and professional relationship with the EPA, but with the regional haze
SIP process, the EPA has not reciprocated the same cooperative effort.
This lack of effort on the part of the EPA does not represent the
intent of what performance partnership agreements are put in place to
accomplish.
Wyoming is a leader in collaboration. Whether it is hydraulic
fracturing, Sage Grouse Core Area Development, or carbon sequestration,
Wyoming has demonstrated a willingness, and really eagerness, to work
with federal agencies, local government, and industry to create
solutions that not only minimize detrimental impact, but may actually
do the opposite: Encouraging sustainable economic growth in Wyoming.
EPA's imposition of the FIP would pour a bucket of cold water on
the solutions resulting from this type of collaboration. In its place,
EPA risks disenfranchising ratepayers when industry has little choice
but to transfer the costs associated with retrofitting the EGUs.
Moreover, because EPA failed to consider the primary cause of regional
haze in Wyoming and the Interior West--smoke from wildfires--it risks
alienating local government and state cooperating agencies who will
perceive EPA as being out of touch with the regulated community.
Response: We disagree with this comment. EPA values its
relationship with the State of Wyoming and prior to our proposed action
had numerous meetings with State and industry representatives to
explore ways in which the State could have addressed our long standing
concerns with the approvability of the State's Regional Haze SIP.
Regrettably, we were unable to find a path forward during those
discussions that could have resulted in the submission of a fully
approvable regional haze SIP. Nevertheless, we remain committed to
working collaboratively with the State on future regional haze actions
and encourage the State to submit a SIP revision that could potentially
replace all or a portion of our FIP. We do note that in a previous
action we finalized full approval of the State's 309 (SO2)
portion of the Regional Haze SIP. In this action we will also be
finalizing approval of many aspects of the State's 309g (NOX
and PM) portion of the regional haze plan.
Comment: We received numerous comments that the regulation of
regional haze is focused on improving visibility, not public health.
Response: We agree with the commenter that the CAA's visibility
program and the RHR are focused on improving visibility and not public
health.
Comment: The Conservation Organizations submitted comments on July
23, 2012 urging EPA not to finalize its proposal to approve Wyoming's
participation in a Western Backstop Trading Program in lieu of
satisfying BART requirements for SO2. Under 40 CFR 51.309,
states within the Grand Canyon Visibility Transport region, including
Wyoming, may adopt a BART-alternative for the state's SO2
emissions provided that, among other things, the program is shown to
provide for greater reasonable progress than would be achieved by
application of BART pursuant to 40 CFR 51.308(e)(2). Wyoming`s
alternative program does not satisfy this requirement. Accordingly,
Wyoming must comply with BART requirements for all haze-causing
pollutants, including SO2.
Response: We finalized approval of the State's 309 SIP that
includes the requirements for the Western Backstop Trading Program on
December 12, 2012 (77 FR 73926). Because this comment pertains to that
final rulemaking, it is not germane to this final rulemaking action.
Comment: Unlike other programs, the regional haze program requires
regular updates and reviews to ensure that reasonable progress is being
made towards the ultimate goal ending in 2064. In fact, the State will
be required to submit a progress report to EPA in 2013 and a new
regional haze SIP in 2018. EPA should approve the Wyoming Regional Haze
SIP, and reserve most of its arguments and concerns expressed in its
regional haze FIP for consideration in Wyoming's 2018 regional haze SIP
submittals. In the meantime, EPA can be assured that the significant
emission reductions required under the Wyoming Regional Haze SIP,
nearly all of which already have been installed, will continue to
contribute to visibility improvement.
Response: Because we have found that the State's Regional Haze SIP
did not adequately satisfy the RHR requirements in full, we have a duty
to promulgate a FIP during this planning period that meets those
requirements.
Comment: EPA pays undue attention to the ``health'' issues in its
FIP. For reasons it does not explain, EPA's FIP discusses the asserted
health impacts of fine particulates, when health impacts are not part
of the BART analysis. The regional haze program is not a health-based
program; rather, it is focused on aesthetics.
Response: We disagree with this comment. In our proposed notice, we
stated that ``PM2.5 can also cause serious health effects
and mortality in humans and contributes to environmental effects such
as acid deposition and eutrophication.'' 78 FR 34741. The commenter
suggests that this brief informational statement somehow means that we
based our BART determinations in part on the health impacts of
PM2.5. This is not the case, as we clearly based our BART
determinations on the five statutory factors, as required by section
169(a) of the CAA and the RHR.
Comment: In light of EPA's apparent coordination with the special
interest groups and the particular influence those groups seemed to be
exerting over EPA's regional haze program, Wyoming and eleven other
states submitted to EPA a Freedom of Information Act (FOIA) request
seeking communications between EPA and the special interest groups
related to EPA action on regional haze SIPs. See Letter from P. Clayton
Eubanks, Deputy Solicitor General, Office of Oklahoma Attorney General,
to FOIA Officer, EPA (Feb. 6, 2013) (FOIA Request). EPA denied the
states' public records request on the ground that the states' fee
waiver request was invalid because the states ``have not expressed a
specific intent to disseminate the information to the public.'' Letter
from Larry F. Gottesman, National FOIA Office, EPA, to Clayton Eubanks,
Deputy Solicitor General, Office of Oklahoma Attorney General (Feb. 22,
2013). But see FOIA Request, at 5-9 (Feb. 6, 2013) (describing in
detail the states' intent to disseminate the information to the
public).
The states appealed that plainly erroneous decision. See Letter
from P. Clayton Eubanks, Deputy Solicitor General, Office of Oklahoma
Attorney General, to National FOIA Officer, EPA (March 15, 2013)
(Exhibit 4). On May 2, 2013, EPA's Office of General Counsel informed
the states that it needed ``a
[[Page 5213]]
brief extension of time''--until May 15, 2013--to respond to the
states' appeal. Electronic mail from Lynn Kelly, Attorney-Advisor, EPA
Office of General Counsel, to P. Clayton Eubanks, Deputy Solicitor
General, Office of Oklahoma Attorney General. Two weeks later, EPA
again informed the states that it needed more time to review the
appeal, promising a decision by May 31, 2013. Electronic mail from Lynn
Kelly, Attorney-Advisor, EPA Office of General Counsel, to P. Clayton
Eubanks, Deputy Solicitor General, Office of Oklahoma Attorney General
(May 15, 2013).
On that date, EPA denied the states' FOIA request, claiming the
states' request ``fails to adequately describe the records sought[.]''
Letter from Kevin M. Miller, Assistant General Counsel, EPA Office of
General Counsel, to P. Clayton Eubanks, Deputy Solicitor General,
Office of Oklahoma Attorney General, at 1 (May 31, 20 13). But see FOIA
Request, at 1-3 (describing in detail the records sought). In the face
of EPA's blatant attempts to frustrate the states' right to access
public records directly related to matters of great importance to the
states and the public, the states sued EPA in federal court. Compl.,
Oklahoma v. EPA, No. 5:13-cv-00726-M (W.D. Okla. July 16, 2013).
In related litigation seeking the documents that the states
requested, as well as others, a federal judge has questioned EPA's
truthfulness and concluded ``that leaders in EPA may have purposefully
attempted to skirt disclosure under the FOIA.'' Mem. Op., at 13,
Landmark Legal Found. v. EPA, No. 12-1726 (D.D.C. Aug. 14, 2013). One
cannot help but to similarly question EPA's honesty and wonder what EPA
is trying to hide.
Response: EPA disagrees with this comment. EPA has not coordinated
with environmental organizations regarding the outcome of this action.
As we explain elsewhere, nothing in the consent decree requires any
particular substantive outcome concerning Wyoming's Regional Haze SIP.
With respect to the allegations made relating to FOIA litigation, EPA
has fully responded to those claims in federal court. In any case, the
issues in the FOIA litigation mentioned by the commenter, such as
whether the FOIA requester reasonably described the records sought, are
unrelated to the commenter's unsupported allegations of coordination
with environmental organizations.
With respect to the commenter's insinuations of bias, EPA firmly
rejects them. We have given careful consideration to all comments and
views submitted, regardless of their origin. In response to some
comments--both from industry and from environmental organizations--we
have acknowledged the merits of the comments and accordingly adjusted
not only our technical analyses, but also our final determinations. We
have also, at our discretion, considered comments from both industry
and from environmental organizations that were submitted after the
close of the comment period. It is hard to imagine what better evidence
there could be that EPA is willing and able to rationally consider
arguments and does not have an unalterably closed mind on the issues in
this action. See Air Transp. Ass'n of Am., Inc. v. Nat'l Mediation Bd.,
663 F.3d 476, 487 (D.C. Cir. 2010) (standard for prejudgment of
rulemaking issues) (citing Ass'n of Nat'l Advertisers, Inc. v. FTC, 627
F.2d 1151 (D.C. Cir. 1979), cert. denied, 447 U.S. 921 (1980)).
VI. Non-Relevant Comments From EPA's Original Proposal
The following is a summary of the significant comments, criticisms,
and new data we received on our initial June 4, 2012 proposed
rulemaking, which we are not responding to because they are no longer
relevant to the action we proposed on June 10, 2013, or the specific
regional haze related action we are taking in this final rulemaking.
A. General Comments
Comment: EPA is proposing to calculate compliance with tons per
year (tpy) BART emissions limits on a rolling 12-month basis. Based on
EPA's proposal, the owner/operator is to calculate and record a new 12-
month rolling average emission rate from the arithmetic average of all
valid hourly emission rates from the continuous emissions monitoring
systems for the current month and the previous 11 months, and to report
the result in tons. The calculation and compliance determination shall
be performed at the end of each calendar month.
Wyoming established BART emissions limits based on a 30-day rolling
average in accordance with 40 CFR part 51 Appendix Y. Wyoming also
established annual emissions limits for units with BART limits. For all
units with BART limits, except Units 1 through 3 at Basin Electric's
Laramie River Station, Wyoming based the annual emissions limits on the
30-day averaged lb/hr emissions limit and full-time operation for 8,760
hours per year.
Wyoming deliberately established these limits on a calendar year
basis to reduce recordkeeping and reporting burdens, without being any
less stringent than what was prescribed under Appendix Y. Every year,
when the Title V emissions inventory is submitted for each of these
facilities, the reported annual emissions can be compared to the annual
BART limits established in the State permits to determine compliance.
Requiring compliance with a 12-month rolling average will result in
unnecessary monitoring, recordkeeping, and reporting, as the 12-month
rolling emissions limit would be based on full-time operation of the
unit and the more stringent 30-day averaged lb/hr value.
Comment: We received a comment from a coalition of physicians that
expressed concerns over the health impacts from air pollution,
particularly particulate matter and ozone.
Comment: We received a comment from a member of the public that
points out the amount of coal production in Wyoming and its
contribution to carbon dioxide and climate change.
B. Basin Electric Laramie River
Comment: Wyoming has overestimated the ability of SNCR to reduce
emissions. EPA is basing its BART determination on the assumption that
LNB+OFA+SNCR can achieve 0.12 lb/MMBtu on a 30-day rolling average.
This means that addition of SNCR must reduce NOX emissions
from the LNB+OFA strategy by another 48%. Given the sensitivity of SNCR
to boiler operation, size, and configuration, we are concerned that
SNCR may not be able to achieve the proposed level of performance on a
consistent basis. For example, our query of CAMD data for 2011 found no
EGUs with SNCR (out of 3,621 coal-fired EGUs) that met 0.12 lb/MMBtu
each month.
Comment: EPA should ensure that SNCR plus LNBs/OFA are capable of
meeting the proposed NOX limit of 0.12 lb/MMBtu, which would
reflect a 43% NOX removal efficiency for SNCR. This level of
removal is approximately twice that considered for other Wyoming
facilities, as well as facilities in other state BART analyses.
Further, in commenting on EPA's BART proposal for Montana's Colstrip
Units 1 and 2, the NPS researched 3,621 coal-fired EGUs with SNCR and
found only two units that could meet 0.15 lb/MMBtu consistently on a
monthly basis. Accordingly, we question whether SNCR plus combustion
controls can achieve a 0.12 lb/MMBtu NOX limit at Laramie
River Station Units 1-3. Should EPA find that this level of control
with SNCR is achievable, and fail to impose adequate BART limits
reflective of SCR capabilities; we request the EPA ensure the proposed
NOX limits are made
[[Page 5214]]
enforceable as a backstop and that if greater removal efficiencies are
achievable, rates be revised downwards within a 12-month period from
the date the technology becomes operable. We also request that level of
ammonia slip not exceed 5ppm, and such limit likewise be made
enforceable.
Comment: EPA's BART analysis for Laramie River Station Units 1-3
improperly relied on cost estimates from Basin Electric that
overestimated capital costs and significantly underestimated operation
and maintenance costs for SNCR. Particularly, Basin Electric
underestimated the cost of reagent. We corrected these errors in our
revised cost calculation using the Sargent & Lundy SNCR cost module
from the IPM, and evaluated the cost of SNCR to reduce NOX
from the 0.21 lb/MMBtu Wyoming BART limit for LNBs/OFA down to EPA's
proposed FIP limit of 0.12 lb/MMBtu which reflects a NOX
reduction across the SNCR of 43%. We also evaluated the cost
effectiveness for an SNCR system designed to achieve 20% NOX
removal, which would equate to a NOX rate of 0.17 lb/MMBtu.
Our revised estimates show the cost effectiveness of SNCR plus
combustion controls is between $2,435/ton and $2,623/ton to meet a 0.12
lb/MMBtu NOX rate (or between $2,062/ton and $2,368/ton to
meet a 0.17 lb/MMBtu NOX rate). These corrected cost
effectiveness values for meeting a 0.12 lb/MMBtu NOX rate
with SNCR are higher than the cost effectiveness values, between
$2,056/ton and $2,109/ton, assumed by EPA.
Comment: EPA relied on SCR cost estimates provided by Basin
Electric that failed to include LNBs/OFA and therefore assumed
unreasonably high construction and operation costs for the SCR.
Comment: A comparison of SCR to EPA's preferred LNB+OFA+SNCR option
shows incremental costs less than $4,000/ton which are well below
values EPA typically accepts. For example, in its proposal to
disapprove part of the North Dakota plan, EPA cited the ``. . .
relatively low incremental cost effectiveness between the two control
options ($4,855 per ton) . . .'' For Laramie River Station, the
National Park Service (NPS) estimates of incremental costs of SCR are
only slightly greater than SCR's average costs, which are reasonable
when compared to costs accepted by other states and EPA.
Comment: Although Basin Electric opposes EPA's SIP disapproval and
FIP, it supports the agency's decision not to require SCR at Laramie
River Station in its proposed FIP. EPA eliminated the option of LNBs/
OFA plus SCR from consideration as BART for the Laramie River Station
because ``the cost effectiveness value is significantly higher than
LNBs with OFA and there is a comparatively small incremental visibility
improvement over LNBs with OFA.'' Basin Electric agrees with and
supports the EPA on this issue.
Comment: EPA's analysis for Basin Electric's Laramie River Station
acknowledged that additional emissions reductions from LNB and OFA were
proposed in the SIP, but did not assess the benefit of these lower
emissions rates. The short term mass emissions rate was reduced to
1,220 lb/hr for Laramie River Station on Units 1 and 2, and reduced to
1,254 lb/hr for Laramie River Station Unit 3. EPA explained that since
the State did not provide additional cost information for the lower
limits, revised modeling based on 0.21 lb/MMBtu was not performed, nor
did EPA perform a revised cost analysis.
The reduced mass emissions are based on a performance level of 0.19
lb/MMBtu, which will be achieved by the installation of LNB with OFA at
no additional cost. Accounting for additional reduction in emissions,
without changing the control costs, yields a significantly higher
incremental cost, approximately $3,300, between LNB with OFA and SNCR.
If EPA had accounted for additional reduction from LNB and OFA and
resulting smaller incremental visibility improvement (less than 0.23
delta deciviews), the State anticipates that SNCR would not have been
BART. This conclusion is based on EPA's determination in the proposed
FIP for Montana that ``. . . the cost of SOFA+SCR ($3,195/ton) [lower
than the incremental cost of SNCR] is not justified by the visibility
improvement of 0.404 deciviews at Theodore Roosevelt National Park and
0.378 deciviews at UL Bend.'' 77 FR 24027.
When evaluating Wyoming's 309(g) Regional Haze SIP, EPA should have
considered the additional NOX emissions reductions achieved
in the SIP before making a final determination on the approvability of
the SIP.
Comment: EPA's comparison of annual emissions from the installation
of SNCR to the annual emissions cap established in a settlement is not
consistent. Operation of SNCR on Laramie River Station Units 1 through
3 is anticipated to result in annual emissions of 8,468 tons per year.
The State established an annual facility emissions cap of 12,773 tons
per year in a permit. The 8,468 tons per year value is based on an
average of 2001-2003 actual heat input for each boiler, while the
12,773 tons of NOX is a facility cap on potential emissions.
Typically, actual emissions are notably less than potential emissions
in order to maintain a margin of compliance. It is the State's
expectation that the emissions difference between EPA's SNCR
determination and the State's reduced facility emissions cap will be
less than the calculated 4,305 tons per year. A more direct comparison
would be to base the difference on the potential to emit for each of
the three Laramie River Station units (0.12 lb/MMBtu times the maximum
heat input rate times 8,760 hours of operation) which yields an annual
facility NOX emission rate of 10,218 tons per year, and a
difference from the State's emission cap of 2,555 tons.
Comment: EPA states ``We find it was unreasonable for the State not
to determine that LNBs with OFA plus SNCR was NOX BART for
LRS Units 1-3.'' This statement provides no insight into the agency's
reasons for disapproving the State's NOX BART for Laramie
River Station.
C. Jim Bridger Units 1-4
Comment: In its regional haze FIP, EPA identifies the relatively
high incremental cost effectiveness of SCR ($5,721 per ton) for the
Bridger units. Nevertheless, EPA does not account for this number in
its own BART decision making. EPA also fails to accord any deference to
Wyoming's consideration of these same costs. Such action is arbitrary
and contrary to EPA's actions in other states. Here, EPA erred by not
considering any incremental costs for Bridger, and by not honoring
Wyoming's consideration of costs for the Bridger units.
Comment: In response to EPA's request for comment on alternative
approaches for the Jim Bridger BART determination, EPA received general
comments in favor of our third proposal in the alternative. Although
these commenters supported our third proposal in the alternative, the
commenters did not provide quantitative information to support their
position.
Comment: EPA is seeking comment on an alternative that would allow
PacifiCorp to install SCR at Jim Bridger Units 3 and 4 within 5 years
from the date of EPA's final action. EPA's reasoning is that this
alternative would allow PacifiCorp the flexibility to determine the
implementation schedule for BART controls on all four Jim Bridger
units. Because EPA's initial proposal to require BART installation by
2016 best complies with the statutory requirement that BART be
installed and operated as expeditiously as practicable, 42 U.S.C.
7491(b)(2)(A), we support EPA's proposal over the alternative.
[[Page 5215]]
Comment: EPA likely underestimated the visibility benefits
attributable to SCR to control NOX emissions in other ways.
First, EPA failed to follow its BART guidelines in estimating pre- and
post-control emissions. EPA's baseline for modeling included the PM and
SO2 limits that will be established by the regional haze
plan, rather than using a pre-SIP baseline (typically from the time
period of 2001-2004) as required by EPA's BART guidelines. This
approach resulted in an understatement of visibility improvement from
NOX BART controls. Further, EPA deviated from its BART
guidelines by modeling baseline emissions that were based on allowable
emission rates rather than actual maximum 24-hour rates. As a result,
EPA's baseline is based on long-term average emissions that mask actual
maximum visibility impairment. Further, EPA greatly overestimates the
ammonia slip (SO4 emissions) associated with SCR. For
example, actual increases in SO4 emissions due to operation
of SCR at each of the Jim Bridger units are 7.89 lb/hr per unit, far
lower than EPA's assumed increase in SO4 emissions of 54.0
lb/hr per unit. This error, too, likely caused EPA to understate the
visibility benefits of SCR.
The Conservation Organizations conducted modeling analyses to
examine how widespread the impacts from each BART-subject source were
and to analyze the widespread visibility improvements that would result
if all units were required to install SCR along with combustion
controls at 0.05 lb/MMBtu limits routinely achieved to meet
NOX BART. The Conservation Organizations did not attempt to
address all of EPA`s errors in their supplemental modeling of
visibility impacts. Had the Conservation Organizations done so (i.e.,
changed baseline to reflect pre-SIP emissions of SO2, PM as
well as NOX, and reduced the projected increase in sulfates
to more reasonable levels), we assume that even greater visibility
benefits would have been demonstrated with SCR required as BART at all
BART-subject units.
D. Dave Johnston Units 3 and 4
Comment: EPA relied on Wyoming's cost-effectiveness analysis of SCR
plus LNBs/OFA at Dave Johnston Unit 3, which significantly
overestimates the cost of this technology. While EPA presented a cost
effectiveness of $3,243/ton, our revised cost-effectiveness calculation
using the Sargent & Lundy SCR cost module shows that SCR plus LNBs/OFA
at Dave Johnston Unit 3 to meet a NOX limit of 0.05 lb/MMBtu
is much lower: $1,632/ton.
Comment: EPA relied on Wyoming's dramatic underestimation of the
cost for SNCR at Dave Johnson Unit 3. Wyoming's BART analysis used
costs provided by PacifiCorp, which greatly underestimated reagent
costs for SNCR. Further, although PacifiCorp's SNCR cost analysis was
based on achieving a NOX rate of 0.22 lb/MMBtu, Wyoming
stated that SNCR was assumed to meet a NOX rate of 0.19 lb/
MMBtu. This skewed the cost-effectiveness results by making SNCR appear
less costly and more effective. Our revised analysis using the Sargent
& Lundy SNCR cost module from the IPM to achieve a 0.22 lb/MMBtu
NOX rate (20% removal across the SNCR) demonstrated that
SNCR has a higher cost-effectiveness value than is presented in the
proposed rule. While EPA presented and relied on a cost effectiveness
for SNCR of $721/ton, correcting the flaws in that analysis
demonstrates a cost effectiveness for SNCR of $1,443/ton. Based on
these corrected cost calculations, the cost of SCR plus LNBs/OFA is
$1,632/ton, not appreciably higher than the cost of SNCR at $1,443/ton.
Comment: EPA makes the same errors in its BART analysis for Dave
Johnston Unit 4 as it did for Unit 3. EPA has proposed to approve
Wyoming's NOX BART determination for Dave Johnston Unit 4,
requiring LNBs with advanced OFA to achieve a NOX emission
limit of 0.15 lb/MMBtu. Although the cost effectiveness of SCR plus
LNBs with OFA at Dave Johnston Unit 4 presented by Wyoming and relied
upon by EPA was abundantly reasonable at $2,210 per ton of
NOX removed, EPA apparently agreed with Wyoming that the
incremental cost effectiveness of these controls compared to LNBs/OFA
was too high to justify SCR as BART.
Wyoming calculated the cost effectiveness of SCR plus LNBs/OFA to
be $2,210/ton with a projected maximum visibility improvement of 0.97
deciviews. In comparison, Wyoming and EPA found that these same
controls constitute BART at Naughton Unit 3, even though the cost was
greater, $2,830/ton, and the projected maximum visibility improvement
was roughly the same, 1.0 deciviews. Wyoming and EPA also found that
SCR plus LNBs and SOFA met BART for Jim Bridger Units 3 and 4 at a cost
effectiveness of $2,258/ton and a projected visibility improvement of
0.80 and 0.82 deciviews, respectively. Further, EPA found that SCR plus
LNBs and SOFA met BART for Jim Bridger Units 1 and 2 at a cost
effectiveness of $2,258/ton and a visibility improvement of 0.76
deciviews and 0.82 deciviews, respectively. EPA's contrary conclusion
for Dave Johnston Unit 4 is arbitrary and inconsistent with EPA's other
decisions.
Comment: Although EPA's data in the proposed rule demonstrated that
SCR plus LNBs/OFA is cost effective at $2,210/ton of NOX
removed, EPA overestimated the cost of SCR for Dave Johnston Unit 4 in
the same way it did for Dave Johnston Unit 3. We recalculated the cost
effectiveness of SCR plus combustion controls at Dave Johnston Unit 4
using the Sargent & Lundy SCR IPM Cost Module to meet a NOX
rate of 0.05 lb/MMBtu. The revised cost analysis shows a cost
effectiveness of $1,837/ton for these controls.
Comment: EPA appears to have placed undue weight on incremental
costs. In its proposal to disapprove part of the North Dakota plan, EPA
cited the ``. . . relatively low incremental cost effectiveness between
the two control options ($4,855 per ton) . . .'' For Johnston units 3
and 4, the NPS estimates of incremental costs of SCR are two--three
times greater than LNB+OFA+SCR's average costs, which are reasonable
when compared to costs accepted by other states and EPA.
E. Naughton Units 1-3
Comment: We received comments that the cost analysis of SCR at
Naughton is over inflated. One commenter estimated that, using a
capital cost of $266/kW, LNB+OFA+SCR for Unit 1 would remove 3,249 tpy
and cost $2,098/ton. The commenter went on to say that they estimated
the cost for the addition of SCR to Unit 2 and Unit 3 would be $2,037
and $2,844/ton. A commenter estimated the costs for the addition of SCR
to Unit 3 would be $1,788/ton. Another commenter estimated the cost of
SCR of $1,550/ton for Naughton Unit 1 and $1,501/ton for Naughton Unit
2.
Comment: Even taken at face value, the $2,750 and $2,848 costs per
ton estimated by Wyoming for LNB+OFA+ SCR on Naughton Units 1 and 2,
respectively, are similar to or lower than the cost/ton values accepted
as reasonable in other BART analyses, including Wyoming's and EPA's
conclusion that addition of OFA+SCR at $2,830/ton is reasonable for
Naughton Unit 3.
Comment: Despite our concerns with the visibility modeling
conducted by EPA, taken at face value, the annual costs and visibility
improvements (presented by EPA) associated with the addition of SCR
result in cost-effectiveness of $9.6 million/deciview for Naughton Unit
1, $11.5 million/deciview for Unit 2, and $15.7 million/deciview for
Unit 3 (which EPA deemed reasonable) at the nearest Class I area.
[[Page 5216]]
All three of these estimates are below or within the range of average
cost/deciview accepted as ``reasonable''.
Comment: EPA relied solely on an incremental cost-benefit rationale
to reject SCR as BART for Naughton Units 1 and 2. This conclusion is
improper where SCR plus combustion controls is cost effective, even
using EPA's inflated numbers, and its visibility benefit would be
significant. Indeed, the costs and visibility benefits of SCR at Units
1 and 2 are nearly identical to the costs and visibility benefits of
SCR at Unit 3, at which EPA found SCR to be BART. Specifically, SCR at
Naughton Units 1 and 2 has a cost effectiveness of $2,750/$2,848 per
ton of NOX removed and results in maximum visibility
improvements of 1.07/1.10 deciviews. Given these very similar numbers,
EPA's determination that SCR is BART at Unit 3 but SCR is not BART at
Units 1 and 2 is arbitrary.
Comment: EPA has placed undue emphasis on incremental cost
effectiveness is even more improper considering its inaccuracy. EPA
stated incorrectly the incremental cost effectiveness of LNBs/OFA plus
SCR compared to LNBs/OFA as $8,000/ton. However, this calculation
actually refers to the incremental cost effectiveness of the SCR option
compared to the SNCR BART option. The incremental cost effectiveness
between the SCR option and the LNB/OFA option based on Wyoming's cost
and emission estimates provided in its BART Application Analyses are
$6,665/ton for Unit 1 and $6,518/ton for Unit 2.
F. Wyodak
Comment: We received comments that the costs for SCR were
overinflated. One commenter estimated that LNB+OFA+SCR would remove
3,773 tpy and cost $3,475/ton. Another commenter estimated that based
on the Sargent & Lundy SCR cost module, the revised cost estimate for
these controls to meet a NOX limit of 0.05 lb/MMBtu is
$2,602/ton of NOX removed.
Comment: As it did for Dave Johnston Unit 3, EPA also relied on
Wyoming's gross underestimate of the costs of SNCR. Rather than the
$958/ton of NOX removed assumed by EPA, the more accurate
cost effectiveness of SNCR based on the Sargent & Lundy SNCR IPM cost
module is $3,139/ton. Thus, SCR is more cost effective than SNCR to
control NOX at Wyodak.
Comment: EPA has placed undue weight on incremental costs and
incremental benefits. Our analysis of the LNB+OFA+SCR option shows an
incremental cost of $3,726/ton for adding SCR to LNB+OFA. Our estimates
of incremental costs of SCR are only slightly greater than
LNB+OFA+SCR's average costs, which are reasonable when compared to
costs accepted by other states and EPA.
G. Dave Johnston Units 1 and 2
Comment: The Conservation Organizations agree with EPA that
reasonable progress controls for NOX emissions are needed
for Dave Johnston Units 1 and 2. EPA correctly found that it was
unreasonable for Wyoming to reject cost effective NOX
controls that would improve visibility. EPA proposes to require only
LNBs/OFA to achieve a NOX emission limit of 0.20 lb/MMBtu
(30-day rolling average). While we commend EPA for proposing a FIP to
reduce NOX emissions from Dave Johnston Units 1 and 2, we
urge EPA to require SCR plus LNBs/OFA to meet a NOX emission
limit of 0.05 lb/MMBtu to achieve reasonable progress. Although EPA
concluded that the cost of SCR is not justified by the projected
visibility improvement, EPA's analysis unreasonably assumed that SCR
would only achieve a NOX emission rate of 0.12 lb/MMBtu,
even though an emission rate of 0.05 lb/MMBtu is readily achievable.
Correcting for this error, it appears that SCR at Dave Johnston Units 1
and 2 is very cost effective at $2,001 and $1,987/ton of NOX
removed, respectively. Accordingly, EPA should reconsider requiring SCR
at Dave Johnston Units 1 and 2 to meet reasonable progress
requirements.
Comment: EPA deviated from the BART Guidelines in the way it
estimated the emission rates it used in its modeling analyses. For Dave
Johnston Unit 1 and Unit 2, EPA assumed that NOX emissions
would drop from 1,012.5 lb/hr (base case) to 354.375 lb/hr with the
addition of LNB+OFA and to 202.5 lb/hr with addition of SCR. However,
our review of 2001-2003 daily CAMD data found that daily NOX
emissions from Johnston Unit 1 and Unit 2 during 2001-2003 never
exceeded 680 lb/hr. EPA modeling analysis cannot be relied upon to
estimate ``a comparatively small incremental visibility improvement''
because the emissions modeled are incorrect.
Comment: The EPA conclusion that the addition of SCR is not
justified due to the ``small incremental visibility improvement'' is
based upon a flawed visibility analysis that over-values the addition
of LNB+OFA and under-values addition of SCR. Furthermore, the degree of
visibility improvement is not one of the four statutory factors to be
considered under the reasonable progress provisions of the RHR.
Incremental visibility improvement is not mentioned anywhere in the
reasonable progress provisions or BART Guidelines and EPA cannot create
a new criterion for the sole purpose of eliminating a control option
that is reasonably cost-effective and would yield a significant
visibility improvement.
H. Modeling
Comment: EPA conducted visibility impact modeling from the Wyoming
sources for its BART and reasonable progress analyses. Unfortunately,
EPA failed to present and/or fully explain the results of its modeling
to the public, thus preventing a complete analysis of the benefits of
installation of SCR on the Wyoming sources. Accordingly, we request
that EPA provide clarification on the following issues: (1) Please
clarify whether the spreadsheet provided in response to our FOIA
request represents EPA's complete and final modeling results. If not,
we request that EPA post all final visibility modeling results to the
docket for this rulemaking, including any post-processing of modeling
results, and allow the public to submit comment on the modeling
results; (2) Please describe and clarify any discrepancies between
EPA's proposed rule and its final modeling results; (3) Please explain
how EPA calculated the visibility results presented in its proposed
rule and provide all data upon which these calculations were made. In
addition, we request that EPA re-run its visibility impact modeling for
years 2001-2003 and incorporate all proposed changes to its modeling
provided in this comment letter, in the TSD, and in the Expert Report
of Howard Gebhart, including, but not limited to utilization of the
correct version of the model, correct emission rates, and compressive
inclusion of impacted Class I areas. We also request that EPA post its
new corrected modeling results to the docket for this rulemaking and
provide the public with an adequate opportunity to respond and comment
on the new visibility impact modeling.
Comment: Wyoming DEQ evaluated visibility improvements at the three
nearest Class I areas--Bridger, Fitzpatrick, and Mount Zirkel
Wilderness Areas--and reported the ``cumulative 3-year averaged
visibility improvement from Post-Control Scenario A across the three
Class I areas . . .'' We requested to DEQ that the other eight Class I
areas within 300 km of Bridger (Grand Teton National Park, Yellowstone
National Park, Rocky Mountain National Park, Washakie
[[Page 5217]]
Wilderness Area, Teton Wilderness Area, Flat Tops Wilderness Area,
Rawah Wilderness Area, and Eagles Nest Wilderness Area) be included in
the modeling analysis. However, instead of expanding the modeling
analysis, EPA R8 reported results for only the Mount Zirkel Wilderness
Area.
Comment: EPA R8 has incorrectly estimated visibility improvement
from all NOX control options: WY DEQ evaluated visibility
improvements at the four nearest Class I areas and reported the ``The
cumulative 3-year averaged 98th percentile visibility improvement from
Post-Control Scenario A summed across all four Class I areas achieved
with Post-Control Scenario B was 0.754 delta deciviews from Unit 3 and
0.405 delta from Unit 4.'' EPA R8 reported results for only one Class I
area. PacifiCorp apparently considered cost a useful metric when it
made the following statements for its Unit 3 BART proposal:
``the incremental cost effectiveness for Scenario 1 compared to the
Baseline is reasonable at $0.4 million per day and $14.4 million per
deciview to improve visibility at Badlands NP'' and for its Unit
4 BART proposal, ``the incremental cost effectiveness for
Scenario 1 compared to the Baseline is reasonable at about $800,000 per
day and $31.7 million per deciview.'' PacifiCorp's conclusions are
consistent with those reached across the country that the average cost
per deciview proposed by either a state or a BART source is $14-$18
million, with a maximum of almost $50 million per deciview proposed by
Colorado at the Martin Drake power plant. Combining the modeling
results provided by EPA R8 (which we believe have underestimated SCR
benefits) and Wyoming DEQ's cost analyses (which we believe have
overestimated SCR costs), addition of SCR at Dave Johnston Unit 3 would
improve visibility by 1.16 deciview at a cost of $14 million per
deciview at the most-impacted Class I area. Likewise, addition of SCR
at Dave Johnston Unit 4 would improve visibility by 0.97 deciview at a
cost of $17 million per deciview. Not only is addition of SCR cost-
effective (even by PacifiCorp's criteria), it would be even more cost-
effective if the issues we have noted above are addressed. By
overestimating costs of SCR and underestimating control efficiency and
visibility benefits, EPA R8 concluded that combustion controls plus
SNCR is BART for Unit 3 and combustion controls are BART for Unit 4,
rather than SCR.
Comment: EPA states that a change of 1.0 deciview is perceptible
and causes visibility impairment and a change of 0.5 deciviews,
although not perceptible, is considered to contribute to visibility
impairment. 40 CFR part 51, App. Y, section III.A.1, 70 FR 39120.
Sources that do not have an impact of 0.5 deciviews or more may be
exempted from BART altogether. 40 CFR part 51, App. Y, section III.A.1.
In Wyoming, EPA approved the State's selection of a 0.5 deciview
threshold for exempting sources from BART, based on the ``relatively
limited impact on visibility'' from sources under the threshold.
In Colorado, the state established criteria that SNCR would be
required as BART only if the cost effectiveness for SNCR was less than
$5,000/ton and the visibility improvement was greater than 0.2
deciviews. Although EPA stated it did ``not necessarily agree'' that
these criteria would always be appropriate for determining BART, it
proposed to approve all BART determinations the state made using these
criteria.
The modeled visibility improvement using the final BART permit
levels that would be achieved with SNCR at Laramie River is one-tenth
of what EPA contends is humanly perceptible, one-fifth of the level
used to exempt Wyoming sources from BART due to relatively limited
visibility impact, and one-half the SNCR threshold used by Colorado to
establish limits that EPA proposed to approve. This de minimis
improvement rebuts EPA's disapproval of the State's NOX BART
for Laramie River, and supports the State's final BART determination.
Even if EPA were entitled to disapprove a state's BART determination
based on a standard of ``unreasonableness,'' it cannot be unreasonable
for the state to fail to require additional SNCR controls that would
offer tiny and imperceptible visibility improvements at enormous cost.
However one characterizes the facts, millions of dollars would be spent
every year to install and operate SNCR.
Moreover, the modeled visibility improvements for the Jim Bridger
units resulting from the requirement to install SCR (as BART under the
EPA regional haze FIP and as part of the LTS under the Wyoming Regional
Haze SIP) are too small to justify the overall expense of requiring
these controls. Spending hundreds of millions of dollars for
imperceptible visibility changes does not meet the intent, or purpose,
of the regional haze program.
Comment: EPA has improperly failed to account for the very few
number of days of visibility impacts or the seasonal timing of when
those few impacts occur. EPA is proposing to accelerate the timeline
for installing the Jim Bridger Unit 1 SCR from 2022 to 2017 and the Jim
Bridger Unit 2 SCR from 2021 to 2017. Even when relying on the CALPUFF
models that significantly overestimate the visibility impacts, EPA's
proposal will only result in imperceptible visibility improvements for
only eleven days a year until the SCRs would have been installed as
required by the State's plan.
In a similar manner, the days of impacts need to be considered when
evaluating the additional controls that EPA proposes to install on
Wyodak and Dave Johnston Unit 3. EPA's modeling of Wyodak indicates
that installing and incurring the additional costs for the SNCR will
not only result in an imperceptible 0.15 deciview of visibility
improvement, but the days per year the unit is modeled to impact the
park by greater than 0.5 deciviews will be reduced from sixteen to
twelve days; a benefit of only four days per year.
EPA's modeling of Dave Johnston Unit 3 indicates that installing
and incurring the additional costs for SNCR will result not only in an
imperceptible 0.17 deciview improvement, but the days per year the unit
is modeled to impact the park by greater than 0.5 deciviews will only
be reduced from nine to six days; a benefit of only three days per
year. None of these imperceptible modeled visibility improvements
occurring during only a few days a year justify the tremendous cost of
controls required under EPA's regional haze FIP.
VII. Statutory and Executive Order Reviews
A. Executive Order 12866: Regulatory Planning and Review and Executive
Order 13563: Improving Regulation and Regulatory Review
This action is not a ``significant regulatory action'' under the
terms of Executive Order 12866 (58 FR 51735, October 4, 1993) and is
therefore not subject to review under Executive Orders 12866 and 13563
(76 FR 3821, January 21, 2011). As discussed in section C below, the
final FIP applies to only three facilities and five BART units.\241\ It
is therefore not a rule of general applicability.
---------------------------------------------------------------------------
\241\ Dave Johnston Unit 3, Laramie River units 1, 2, and 3, and
the unit at Wyodak.
---------------------------------------------------------------------------
B. Paperwork Reduction Act
This action does not impose an information collection burden under
the provisions of the Paperwork Reduction Act, 44 U.S.C. 3501 et seq.
Burden is defined at 5 CFR 1320.3(b). Because the final FIP applies to
just three facilities, the Paperwork Reduction Act does not apply. See
5 CFR 1320(c).
[[Page 5218]]
C. Regulatory Flexibility Act
The Regulatory Flexibility Act (RFA) generally requires an agency
to prepare a regulatory flexibility analysis of any rule subject to
notice and comment rulemaking requirements under the Administrative
Procedure Act or any other statute unless the agency certifies that the
rule will not have a significant economic impact on a substantial
number of small entities. Small entities include small businesses,
small organizations, and small governmental jurisdictions.
For purposes of assessing the impacts of today's final rule on
small entities, small entity is defined as: (1) A small business as
defined by the Small Business Administration's (SBA) regulations at 13
CFR 121.201; (2) a small governmental jurisdiction that is a government
of a city, county, town, school district or special district with a
population of less than 50,000; and (3) a small organization that is
any not-for-profit enterprise which is independently owned and operated
and is not dominant in its field.
After considering the economic impacts of today's final rule on
small entities, I certify that this action will not have a significant
economic impact on a substantial number of small entities. The Regional
Haze FIP that EPA is finalizing for purposes of the regional haze
program consists of imposing federal controls to meet the BART
requirement for NOX emissions on five specific BART units at
three facilities in Wyoming. The net result of this FIP action is that
EPA is finalizing direct emission controls on selected units at only
three sources. The sources in question are each large electric
generating plants that are not owned by small entities, and therefore
are not small entities. The final partial approval of the SIP merely
approves state law as meeting Federal requirements and does not impose
additional requirements. See, e.g., Mid-Tex Electric Cooperative, Inc.
v. FERC, 773 F.2d 327 (D.C. Cir. 1985)(hereinafter Mid-Tex).
D. Unfunded Mandates Reform Act (UMRA)
Title II of the Unfunded Mandates Reform Act of 1995 (UMRA), Public
Law 104-4, establishes requirements for federal agencies to assess the
effects of their regulatory actions on State, local, and Tribal
governments and the private sector. Under section 202 of UMRA, EPA
generally must prepare a written statement, including a cost-benefit
analysis, for final rules with ``Federal mandates'' that may result in
expenditures to State, local, and Tribal governments, in the aggregate,
or to the private sector, of $100 million or more (adjusted for
inflation) in any one year. Before promulgating an EPA rule for which a
written statement is needed, section 205 of UMRA generally requires EPA
to identify and consider a reasonable number of regulatory alternatives
and adopt the least costly, most cost-effective, or least burdensome
alternative that achieves the objectives of the rule. The provisions of
section 205 of UMRA do not apply when they are inconsistent with
applicable law. Moreover, section 205 of UMRA allows EPA to adopt an
alternative other than the least costly, most cost-effective, or least
burdensome alternative if the Administrator publishes with the final
rule an explanation why that alternative was not adopted. Before EPA
establishes any regulatory requirements that may significantly or
uniquely affect small governments, including Tribal governments, it
must have developed under section 203 of UMRA a small government agency
plan. The plan must provide for notifying potentially affected small
governments, enabling officials of affected small governments to have
meaningful and timely input in the development of EPA regulatory
actions with significant federal intergovernmental mandates, and
informing, educating, and advising small governments on compliance with
the regulatory requirements.
Under Title II of UMRA, EPA has determined that this final rule
does not contain a federal mandate that may result in expenditures that
exceed the inflation-adjusted UMRA threshold of $100 million ($150 in
2013 when adjusted for inflation) by State, local, or Tribal
governments or the private sector in any one year. The private sector
expenditures that will result from the FIP, including BART controls for
Basin Electric Laramie River Station Units 1-3 ($67,128,584 per year)
\242\, and PacifiCorp Dave Johnston Unit 3 ($11,680,144 per year) \243\
and Wyodak ($15,073,502) \244\, are $93,882,230 per year. This
calculation assumes that PacifiCorp would choose to install SCR on Dave
Johnston Unit 3, and not to otherwise voluntarily retire the unit, an
option which the FIP allows. Additionally, we do not foresee
significant costs (if any) for state and local governments. Thus,
because the annual expenditures associated with the FIP are less than
the inflation-adjusted threshold of $150 million in any one year, this
rule is not subject to the requirements of sections 202 or 205 of UMRA.
This rule is also not subject to the requirements of section 203 of
UMRA because it contains no regulatory requirements that might
significantly or uniquely affect small governments.
---------------------------------------------------------------------------
\242\ Andover Technology Partners, ``Cost of NOX
Controls on Wyoming EGUs'', October 28, 2013; Wyoming EGU BART and
Reasonable Progress Costs--10/2013.
\243\ Andover Technology Partners, ``Cost of NOX
Controls on Wyoming EGUs'', October 28, 2013; Wyoming EGU BART and
Reasonable Progress Costs--10/2013.
\244\ Andover Technology Partners, ``Cost of NOX
Controls on Wyoming EGUs'', October 28, 2013; Wyoming EGU BART and
Reasonable Progress Costs--10/2013.
---------------------------------------------------------------------------
E. Executive Order 13132: Federalism
Executive Order 13132, Federalism, (64 FR 43255, August 10, 1999)
revokes and replaces Executive Orders 12612 (Federalism) and 12875
(Enhancing the Intergovernmental Partnership). Executive Order 13132
requires EPA to develop an accountable process to ensure ``meaningful
and timely input by State and local officials in the development of
regulatory policies that have federalism implications.'' ``Policies
that have federalism implications'' is defined in the Executive Order
to include regulations that have ``substantial direct effects on the
States, on the relationship between the national government and the
States, or on the distribution of power and responsibilities among the
various levels of government.'' Under Executive Order 13132, EPA may
not issue a regulation that has federalism implications, that imposes
substantial direct compliance costs, and that is not required by
statute, unless the federal government provides the funds necessary to
pay the direct compliance costs incurred by state and local
governments, or EPA consults with state and local officials early in
the process of developing the final regulation. EPA also may not issue
a regulation that has federalism implications and that preempts state
law unless the Agency consults with state and local officials early in
the process of developing the final regulation.
This rule will not have substantial direct effects on the states,
on the relationship between the national government and the states, or
on the distribution of power and responsibilities among the various
levels of government, as specified in Executive Order 13132, because it
merely addresses the State not fully meeting its obligation under the
CAA to include in its SIP provisions to meet the visibility
requirements of Part C of Title I of the CAA and to prohibit emissions
from interfering with other states measures to protect visibility.
Thus, Executive Order 13132 does not apply to this action.
[[Page 5219]]
F. Executive Order 13175: Consultation and Coordination With Indian
Tribal Governments
Executive Order 13175, entitled Consultation and Coordination with
Indian Tribal Governments (65 FR 67249, November 9, 2000), requires EPA
to develop an accountable process to ensure ``meaningful and timely
input by tribal officials in the development of regulatory policies
that have tribal implications.'' This final rule does not have tribal
implications, as specified in Executive Order 13175. It will not have
substantial direct effects on tribal governments. Thus, Executive Order
13175 does not apply to this rule.
G. Executive Order 13045: Protection of Children From Environmental
Health Risks and Safety Risks
EPA interprets EO 13045 (62 FR 19885, April 23, 1997) as applying
only to those regulatory actions that concern health or safety risks,
such that the analysis required under section 5-501 of the EO has the
potential to influence the regulation. This action is not subject to EO
13045 because it implements specific standards established by Congress
in statutes. However, to the extent this final rule will limit
emissions of NOX and PM, the rule will have a beneficial
effect on children's health by reducing air pollution.
H. Executive Order 13211: Actions Concerning Regulations That
Significantly Affect Energy Supply, Distribution, or Use
This action is not subject to Executive Order 13211 (66 FR 28355
(May 22, 2001)), because it is not a significant regulatory action
under Executive Order 12866.
I. National Technology Transfer and Advancement Act
Section 12(d) of the National Technology Transfer and Advancement
Act of 1995 (``NTTAA''), Public Law 104-113, 12(d) (15 U.S.C. 272 note)
directs EPA to use voluntary consensus standards in its regulatory
activities unless to do so would be inconsistent with applicable law or
otherwise impractical. Voluntary consensus standards are technical
standards (e.g., materials specifications, test methods, sampling
procedures, and business practices) that are developed or adopted by
voluntary consensus standards bodies. NTTAA directs EPA to provide
Congress, through OMB, explanations when the Agency decides not to use
available and applicable voluntary consensus standards.
This final rulemaking does not involve technical standards.
Therefore, EPA is not considering the use of any voluntary consensus
standards.
J. Executive Order 12898: Federal Actions To Address Environmental
Justice in Minority Populations and Low-Income Populations
Executive Order 12898 (59 FR 7629, February 16, 1994), establishes
federal executive policy on environmental justice. Its main provision
directs federal agencies, to the greatest extent practicable and
permitted by law, to make environmental justice part of their mission
by identifying and addressing, as appropriate, disproportionately high
and adverse human health or environmental effects of their programs,
policies, and activities on minority populations and low-income
populations in the United States.
We have determined that this final action will not have
disproportionately high and adverse human health or environmental
effects on minority or low-income populations because it increases the
level of environmental protection for all affected populations without
having any disproportionately high and adverse human health or
environmental effects on any population, including any minority or low-
income population. This final rule limits emissions of NOX
from three facilities and five BART units in Wyoming. The partial
approval of the SIP merely approves state law as meeting Federal
requirements and imposes no additional requirements beyond those
imposed by state law.
K. Congressional Review Act
The Congressional Review Act, 5 U.S.C 801 et seq., as added by the
Small Business Regulatory Enforcement Fairness Act of 1996, generally
provides that before a rule may take effect, the agency promulgating
the rule must submit a rule report, which includes a copy of the rule,
to each House of the Congress and to the Comptroller General of the
United States. Section 804 exempts from section 801 the following types
of rules (1) rules of particular applicability; (2) rules relating to
agency management or personnel; and (3) rules of agency organization,
procedure, or practice that do not substantially affect the rights or
obligations of non-agency parties. 5 U.S. 804(3). EPA is not required
to submit a rule report regarding today's action under section 801
because this is a rule of particular applicability. This rule finalizes
a FIP for three sources.
L. Judicial Review
Under section 307(b)(1) of the CAA, petitions for judicial review
of this action must be filed in the United States Court of Appeals for
the appropriate circuit by March 31, 2014. Pursuant to CAA section
307(d)(1)(B), this action is subject to the requirements of CAA section
307(d) as it promulgates a FIP under CAA section 110(c). Filing a
petition for reconsideration by the Administrator of this final rule
does not affect the finality of this action for the purposes of
judicial review nor does it extend the time within which a petition for
judicial review may be filed, and shall not postpone the effectiveness
of such rule or action. This action may not be challenged later in
proceedings to enforce its requirements. See CAA section 307(b)(2).
List of Subjects in 40 CFR Part 52
Environmental protection, Air pollution control, Incorporation by
reference, Intergovernmental relations, Nitrogen dioxide, Particulate
matter, Reporting and recordkeeping requirements, Sulfur oxides,
Volatile organic compounds.
Dated: January 10, 2014.
Gina McCarthy,
Administrator, U.S. EPA.
40 CFR part 52 is amended to read as follows:
PART 52--APPROVAL AND PROMULGATION OF IMPLEMENTATION PLANS
0
1. The authority citation for part 52 continues to read as follows:
Authority: 42 U.S.C. 7401 et seq.
Subpart ZZ--Wyoming
0
2. Section 52.2620, in the table in paragraph (e) is amended by adding
an entry for ``XXIII. Wyoming State Implementation Plan for Regional
Haze for 309(g)'' at the end of the table.
Sec. 52.2620 Identification of plan.
* * * * *
(e) * * *
[[Page 5220]]
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Name of nonregulatory SIP Applicable geographic or State submittal date/ EPA approval date
provision nonattainment area adopted date and citation \3\ Explanations
--------------------------------------------------------------------------------------------------------------------------------------------------------
* * * * * * *
XXIII. Wyoming State Statewide................ Submitted: 1/30/14, [Insert Excluding portions of the following: Chapter
Implementation Plan for Regional 1/12/2011........... Federal Register 6.4, Chapter 6.5.5, Chapter 6.5.7, Chapter
Haze for 309(g). page number where 6.5.8, and Chapter 7.5. We are excluding
the document portions of these chapters because EPA
begins.]. disapproved: (1) The NOX BART
determinations for: (1) Laramie River Units
1-3, Dave Johnston Unit 3, and Wyodak Unit
1; (2) the State's monitoring,
recordkeeping, and reporting requirements
for BART units; (3) the State's reasonable
progress goals.
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\3\ In order to determine the EPA effective date for a specific
provision listed in this table, consult the Federal Register notice
cited in this column for the particular provision.
0
3. Add Sec. 52.2636 to subpart ZZ to read as follows:
Sec. 52.2636 Implementation plan for regional haze.
(a) Applicability. (1) This section applies to each owner and
operator of the following emissions units in the State of Wyoming for
which EPA approved the State's BART determination:
(i) FMC Westvaco Trona Plant Units NS-1A and NS-1B (PM and
NOX);
(ii) TATA Chemicals Partners (previously General Chemical) Boilers
C and D (PM and NOX);
(iii) Basin Electric Power Cooperative Laramie River Station Units
1, 2, and 3 (PM);
(iv) PacifiCorp Dave Johnston Power Plant Unit 3 (PM);
(v) PacifiCorp Dave Johnston Power Plant Unit 4 (PM and
NOX);
(vi) PacifiCorp Jim Bridger Power Plant Units 1, 2, 3, and 4 (PM
and NOX);
(vii) PacifiCorp Naughton Power Plant Units 1, 2, and 3 (PM and
NOX); and
(viii) PacifiCorp Wyodak Power Plant Unit 1 (PM).
(2) This section also applies to each owner and operator of the
following emissions units in the State of Wyoming for which EPA
disapproved the State's BART determination and issued a NOX
BART Federal Implementation Plan:
(i) Basin Electric Power Cooperative Laramie River Station Units 1,
2, and 3;
(ii) PacifiCorp Dave Johnston Unit 3; and
(iii) PacifiCorp Wyodak Power Plant Unit 1.
(b) Definitions. Terms not defined below shall have the meaning
given them in the Clean Air Act or EPA's regulations implementing the
Clean Air Act. For purposes of this section:
(1) BART means Best Available Retrofit Technology.
(2) BART unit means any unit subject to a Regional Haze emission
limit in Table 1 and Table 2 of this section.
(3) CAM means Compliance Assurance Monitoring as required by 40 CFR
part 64.
(4) Continuous emission monitoring system or CEMS means the
equipment required by this section to sample, analyze, measure, and
provide, by means of readings recorded at least once every 15 minutes
(using an automated data acquisition and handling system (DAHS)), a
permanent record of NOX emissions, diluent, or stack gas
volumetric flow rate.
(5) FIP means Federal Implementation Plan.
(6) The term lb/hr means pounds per hour.
(7) The term lb/MMBtu means pounds per million British thermal
units of heat input to the fuel-burning unit.
(8) NOX means nitrogen oxides.
(9) Operating day means a 24-hour period between 12 midnight and
the following midnight during which any fuel is combusted at any time
in the BART unit. It is not necessary for fuel to be combusted for the
entire 24-hour period.
(10) The owner/operator means any person who owns or who operates,
controls, or supervises a unit identified in paragraph (a) of this
section.
(11) PM means filterable total particulate matter.
(12) Unit means any of the units identified in paragraph (a) of
this section.
(c) Emissions limitations. (1) The owners/operators of emissions
units subject to this section shall not emit, or cause to be emitted,
PM or NOX in excess of the following limitations:
Table 1 to Sec. 52.2636
[Emission limits for BART units for which EPA approved the State's BART and Reasonable Progress determinations]
----------------------------------------------------------------------------------------------------------------
NOX emission
PM emission limits-- lb/
Source name/BART unit limits--lb/MMBtu MMBtu (30-day
rolling average)
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FMC Westvaco Trona Plant/Unit NS-1A......................................... 0.05 0.35
FMC Westvaco Trona Plant/Unit NS-1B......................................... 0.05 0.35
TATA Chemicals Partners (General Chemical) Green River Trona Plant/Boiler C. 0.09 0.28
TATA Chemicals Partners (General Chemical) Green River Trona Plant/Boiler D. 0.09 0.28
Basin Electric Power Cooperative Laramie River Station/Unit 1............... 0.03 N/A
Basin Electric Power Cooperative Laramie River Station/Unit 2............... 0.03 N/A
Basin Electric Power Cooperative Laramie River Station/Unit 3............... 0.03 N/A
PacifiCorp Dave Johnston Power Plant/Unit 3................................. 0.015 N/A
[[Page 5221]]
PacifiCorp Dave Johnston Power Plant/Unit 4................................. 0.015 0.15
PacifiCorp Jim Bridger Power Plant/Unit 1 \1\............................... 0.03 0.26/0.07
PacifiCorp Jim Bridger Power Plant/Unit 2 \1\............................... 0.03 0.26/0.07
PacifiCorp Jim Bridger Power Plant/Unit 3 \1\............................... 0.03 0.26/0.07
PacifiCorp Jim Bridger Power Plant/Unit 4 \1\............................... 0.03 0.26/0.07
PacifiCorp Naughton Power Plant/Unit 1...................................... 0.04 0.26
PacifiCorp Naughton Power Plant/Unit 2...................................... 0.04 0.26
PacifiCorp Naughton Power Plant/Unit 3...................................... 0.015 0.07
PacifiCorp Wyodak Power Plant/Unit 1........................................ 0.015 N/A
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\1\ The owners and operators of PacifiCorp Jim Bridger Units 1, 2, 3, and 4 shall comply with the NOX emission
limit for BART of 0.26 lb/MMBtu and PM emission limit for BART of 0.03 lb/MMBtu and other requirements of this
section by March 4, 2019. The owners and operators of PacifiCorp Jim Bridger Units 1, 2, 3 and 4 shall comply
with the NOX emission limit for reasonable progress of 0.07 lb/MMBtu by: December 31, 2022 for Unit 1,
December 31, 2021 for Unit 2, December 31, 2015, for Unit 3, and December 31, 2016, for Unit 4.
Table 2 to Sec. 52.2636
[Emission limits for BART units for which EPA disapproved the State's
BART determination and implemented a FIP]
------------------------------------------------------------------------
NOX
emission
limit--lb/
Source name/BART unit MMBtu (30-
day
rolling
average)
------------------------------------------------------------------------
Basin Electric Power Cooperative Laramie River Station/Unit 0.07
1.........................................................
Basin Electric Power Cooperative Laramie River Station/Unit 0.07
2.........................................................
Basin Electric Power Cooperative Laramie River Station/Unit 0.07
3.........................................................
PacifiCorp Dave Johnston Unit 3............................ *0.07
PacifiCorp Wyodak Power Plant/Unit 1....................... 0.07
------------------------------------------------------------------------
* (or 0.28 and shut-down-by December 31, 2027).
(2) These emission limitations shall apply at all times, including
startups, shutdowns, emergencies, and malfunctions.
(d) Compliance date. (1) The owners and operators of PacifiCorp Jim
Bridger Units 1, 2, 3, and 4 shall comply with the NOX
emission limit of 0.26 lb/MMBtu and PM emission limit of 0.03 lb/MMBtu
and other requirements of this section by March 4, 2019. The owners and
operators of PacifiCorp Jim Bridger Units 1, 2, 3 and 4 shall comply
with the NOX emission limit of 0.07 lb/MMBtu by: December
31, 2022 for Unit 1, December 31, 2021 for Unit 2, December 31, 2015,
for Unit 3, and December 31, 2016, for Unit 4.
(2) The owners and operators of the other BART sources subject to
this section shall comply with the emissions limitations and other
requirements of this section by March 4, 2019.
(3) Compliance alternatives for PacifiCorp Dave Johnston Unit 3.
(i) The owners and operators of PacifiCorp Dave Johnston Unit 3 will
meet a NOX emission limit of 0.07 lb/MMBtu (30-day rolling
average) by March 4, 2019; or
(ii) Alternatively, the owners and operators of PacifiCorp Dave
Johnston Unit 3 will permanently cease operation of this unit on or
before December 31, 2027.
(e) Compliance determinations for NOX. (1) For all BART units other
than Trona Plant units:
(i) CEMS. At all times after the earliest compliance date specified
in paragraph (d) of this section, the owner/operator of each unit shall
maintain, calibrate, and operate a CEMS, in full compliance with the
requirements found at 40 CFR part 75, to accurately measure
NOX, diluent, and stack gas volumetric flow rate from each
unit. The CEMS shall be used to determine compliance with the emission
limitations in paragraph (c) of this section for each unit.
(ii) Method. (A) For any hour in which fuel is combusted in a unit,
the owner/operator of each unit shall calculate the hourly average
NOX emission rate in lb/MMBtu at the CEMS in accordance with
the requirements of 40 CFR part 75. At the end of each operating day,
the owner/operator shall calculate and record a new 30-day rolling
average emission rate in lb/MMBtu from the arithmetic average of all
valid hourly emission rates from the CEMS for the current operating day
and the previous 29 successive operating days.
(B) An hourly average NOX emission rate in lb/MMBtu is
valid only if the minimum number of data points, as specified in 40 CFR
part 75, is acquired by both the pollutant concentration monitor
(NOX) and the diluent monitor (O2 or
CO2).
(C) Data reported to meet the requirements of this section shall
not include data substituted using the missing data substitution
procedures of subpart D of 40 CFR part 75, nor shall the data have been
bias adjusted according to the procedures of 40 CFR part 75.
(2) For all Trona Plant BART units:
(i) CEMS. At all times after the compliance date specified in
paragraph (d) of this section, the owner/operator of each unit shall
maintain, calibrate, and operate a CEMS, in full compliance with
[[Page 5222]]
the requirements found at 40 CFR part 60, to accurately measure
NOX, diluent, and stack gas volumetric flow rate from each
unit, including the CEMS quality assurance requirements in appendix F
of 40 CFR part 60. The CEMS shall be used to determine compliance with
the emission limitations in paragraph (c) of this section for each
unit.
(ii) Method. (A) For any hour in which fuel is combusted in a unit,
the owner/operator of each unit shall calculate the hourly average
NOX emission rate in lb/MMBtu at the CEMS in accordance with
the requirements of 40 CFR part 60. At the end of each operating day,
the owner/operator shall calculate and record a new 30-day rolling
average emission rate in lb/MMBtu from the arithmetic average of all
valid hourly emission rates from the CEMS for the current operating day
and the previous 29 successive operating days.
(B) An hourly average NOX emission rate in lb/MMBtu is
valid only if the minimum number of data points, as specified in 40 CFR
part 60, is acquired by both the pollutant concentration monitor
(NOX) and the diluent monitor (O2 or
CO2).
(f) Compliance determinations for particulate matter. Compliance
with the particulate matter emission limit for each BART unit shall be
determined from annual performance stack tests. Within 60 days of the
compliance deadline specified in paragraph (d) of this section, and on
at least an annual basis thereafter, the owner/operator of each unit
shall conduct a stack test on each unit to measure particulate
emissions using EPA Method 5, 5B, 5D, or 17, as appropriate, in 40 CFR
part 60, Appendix A. A test shall consist of three runs, with each run
at least 120 minutes in duration and each run collecting a minimum
sample of 60 dry standard cubic feet. Results shall be reported in lb/
MMBtu. In addition to annual stack tests, the owner/operator shall
monitor particulate emissions for compliance with the BART emission
limits in accordance with the applicable Compliance Assurance
Monitoring (CAM) plan developed and approved by the State in accordance
with 40 CFR part 64.
(g) Recordkeeping. The owner/operator shall maintain the following
records for at least five years:
(1) All CEMS data, including the date, place, and time of sampling
or measurement; parameters sampled or measured; and results.
(2) Records of quality assurance and quality control activities for
emissions measuring systems including, but not limited to, any records
required by 40 CFR part 75. Or, for Trona Plant units, records of
quality assurance and quality control activities for emissions
measuring systems including, but not limited to appendix F of 40 CFR
part 60.
(3) Records of all major maintenance activities conducted on
emission units, air pollution control equipment, and CEMS.
(4) Any other CEMS records required by 40 CFR part 75. Or, for
Trona Plant units, any other CEMs records required by 40 CFR part 60.
(5) Records of all particulate stack test results.
(6) All data collected pursuant to the CAM plan.
(h) Reporting. All reports under this section shall be submitted to
the Director, Office of Enforcement, Compliance and Environmental
Justice, U.S. Environmental Protection Agency, Region 8, Mail Code
8ENF-AT, 1595 Wynkoop Street, Denver, Colorado 80202-1129.
(1) The owner/operator of each unit shall submit quarterly excess
emissions reports for NOX BART units no later than the 30th
day following the end of each calendar quarter. Excess emissions means
emissions that exceed the emissions limits specified in paragraph (c)
of this section. The reports shall include the magnitude, date(s), and
duration of each period of excess emissions, specific identification of
each period of excess emissions that occurs during startups, shutdowns,
and malfunctions of the unit, the nature and cause of any malfunction
(if known), and the corrective action taken or preventative measures
adopted.
(2) The owner/operator of each unit shall submit quarterly CEMS
performance reports, to include dates and duration of each period
during which the CEMS was inoperative (except for zero and span
adjustments and calibration checks), reason(s) why the CEMS was
inoperative and steps taken to prevent recurrence, and any CEMS repairs
or adjustments. The owner/operator of each unit shall also submit
results of any CEMS performance tests required by 40 CFR part 75. Or,
for Trona Plant units, the owner/operator of each unit shall also
submit results of any CEMs performance test required appendix F of 40
CFR part 60 (Relative Accuracy Test Audits, Relative Accuracy Audits,
and Cylinder Gas Audits).
(3) When no excess emissions have occurred or the CEMS has not been
inoperative, repaired, or adjusted during the reporting period, such
information shall be stated in the quarterly reports required by
paragraphs (h)(1) and (2) of this section.
(4) The owner/operator of each unit shall submit results of any
particulate matter stack tests conducted for demonstrating compliance
with the particulate matter BART limits in paragraphs (c) of this
section, within 60 calendar days after completion of the test.
(5) The owner/operator of each unit shall submit semi-annual
reports of any excursions under the approved CAM plan in accordance
with the schedule specified in the source's title V permit.
(i) Notifications. (1) The owner/operator shall promptly submit
notification of commencement of construction of any equipment which is
being constructed to comply with the NOX emission limits in
paragraph (c) of this section.
(2) The owner/operator shall promptly submit semi-annual progress
reports on construction of any such equipment.
(3) The owner/operator shall promptly submit notification of
initial startup of any such equipment.
(j) Equipment operation. At all times, the owner/operator shall
maintain each unit, including associated air pollution control
equipment, in a manner consistent with good air pollution control
practices for minimizing emissions.
(k) Credible evidence. Nothing in this section shall preclude the
use, including the exclusive use, of any credible evidence or
information, relevant to whether a source would have been in compliance
with requirements of this section if the appropriate performance or
compliance test procedures or method had been performed.
0
4. Add Sec. 52.2637 to subpart ZZ to read as follows:
Sec. 52.2637 Federal implementation plan for reasonable attributable
visibility impairment long-term strategy.
As required by 40 CFR 41.306(c), EPA will ensure that the review of
the State's reasonably attributable visibility impairment long-term
strategy is coordinated with the regional haze long-term strategy under
40 CFR 51.308(g). EPA's review will be in accordance with the
requirements of 40 CFR 51.306(c).
[FR Doc. 2014-00930 Filed 1-29-14; 8:45 am]
BILLING CODE 6560-50-P
