Prevention of Significant Deterioration (PSD) and Non-attainment New Source Review (NSR): Equipment Replacement Provision of the Routine Maintenance, Repair and Replacement Exclusion: Reconsideration, 33838-33850 [05-11546]
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a. Postage due First-Class Mail pieces
are rerouted as First-Class Mail postage
due. Only the original postage due
amount is collected. There is no
additional charge for rerouting the
mailpiece.
b. Postage due Priority Mail pieces are
rerouted as Priority Mail postage due.
Only the original postage due amount is
collected. There is no additional charge
for rerouting the mailpiece.
c. Postage due for all Package Services
pieces, other than oversized Parcel Post
pieces, are rerouted as Priority Mail.
The total postage due for Package
Services pieces is the sum of the postage
due at the time of receipt at the primary
post office plus the postage due for
rerouting the piece from the primary
post office to the temporary post office
at the appropriate Priority Mail rate.
d. Postage due oversized Parcel Post
pieces are rerouted as Parcel Post. The
total postage due is the sum of the
postage due at the time of receipt at the
primary post office and the postage due
for rerouting the piece from the primary
post office to the temporary post office
at the appropriate oversized Parcel Post
rate.
8.6 USPS Responsibility
The delivery post office serving a PFS
customer’s primary address must:
a. Prepare and send the PFS
shipments once each week, on
Wednesdays.
b. Ensure that PFS shipments end in
accordance with the original or revised
end date specified on the application
form, and that delivery to the primary
address begins (or holding mail
commences under 507.3.4.4) as
designated by the customer.
c. Ensure that Label 85 (Permit No. G–
400) is properly affixed to each
reshipped PFS Priority Mail package.
Postage meter or PVI postage must not
be affixed.
*
*
*
*
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Neva R. Watson,
Attorney, Legislative.
[FR Doc. 05–11472 Filed 6–9–05; 8:45 am]
BILLING CODE 7710–12–P
ENVIRONMENTAL PROTECTION
AGENCY
issues raised by the petitioners, we deny
the requests for reconsideration.
40 CFR Parts 51 and 52
DATES:
[FRL–7923–3; E–Docket ID No. OAR–2002–
0068]
ADDRESSES:
RIN 2060–AM58
Prevention of Significant Deterioration
(PSD) and Non-attainment New Source
Review (NSR): Equipment
Replacement Provision of the Routine
Maintenance, Repair and Replacement
Exclusion: Reconsideration
Environmental Protection
Agency (EPA).
ACTION: Notice of final action on
reconsideration.
AGENCY:
SUMMARY: On October 27, 2003, and
December 24, 2003, the EPA revised
regulations governing the major New
Source Review (NSR) programs
mandated by parts C and D of title I of
the Clean Air Act (CAA or Act). The
rule changes from October 27, 2003,
provide a category of equipment
replacement activities that are deemed
to be routine maintenance, repair and
replacement (RMRR) activities and,
therefore, are not subject to Major NSR
requirements under the exclusion, while
the December 24, 2003 rule changes
amended the Prevention of Significant
Deterioration (PSD) provisions of state
programs that did not have approved
state rules for PSD. Also on December
24, 2003, the U.S. Court of Appeals for
the District of Columbia Circuit stayed
the new RMRR rules, pending judicial
review. Following these actions, the
Administrator received petitions for
reconsideration. On July 1, 2004, we,
the EPA, announced our reconsideration
of certain issues arising from these two
final rules and requested comment on
those issues. After carefully considering
all of the comments and information
received through our reconsideration
process, we have concluded that no
additional changes are necessary to the
final rules. With respect to all other
SIC a
Industry group
Electric Services ........................................................
Petroleum Refining ....................................................
Industrial Inorganic Chemicals ..................................
Industrial Organic Chemicals ....................................
Miscellaneous Chemical Products ............................
Natural Gas Liquids ...................................................
Natural Gas Transport ...............................................
Pulp and Paper Mills .................................................
Paper Mills .................................................................
Automobile Manufacturing .........................................
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This final action is effective on
June 10, 2005.
PO 00000
Mr.
David J. Svendsgaard, Information
Transfer and Program Integration
Division (C339–03), U.S. Environmental
Protection Agency, Research Triangle
Park, NC 27711, telephone number:
(919) 541–2380; fax number: (919) 541–
5509, or electronic mail at
svendsgaard.dave@epa.gov.
FOR FURTHER INFORMATION CONTACT:
SUPPLEMENTARY INFORMATION:
I. General Information
A. What are the Regulated Entities?
Entities potentially affected by the
subject rule for today’s action include
sources in all industry groups. The
majority of sources potentially affected
are expected to be in the following
groups.
NAICS b
491
291
281
286
289
132
492
261
262
371
Frm 00042
EPA has established a
docket for this action under Docket ID
No. OAR–2002–0068 (Legacy Number
A–2002–04). All documents in the
docket are listed in the index. Although
listed in the index, some information is
not publicly available, i.e., CBI or other
information whose disclosure is
restricted by statute. Publicly available
docket materials are available in hard
copy either electronically in the
EDOCKET at https://www.epa.gov/
edocket or in hard copy at the U.S.
Environmental Protection Agency, EPA
West (Air Docket), 1200 Pennsylvania
Avenue, Northwest, B102, Mail code:
6102T, Washington, DC 20460,
Attention Docket ID No. OAR–2002–
0068, Washington, DC 20004. The
Public Reading Room is open from 8:30
a.m. to 4:30 p.m., Monday through
Friday, excluding legal holidays. The
telephone number for the Public
Reading Room is (202) 566–1744, and
the telephone number for the Docket is
(202) 566–1742.
221111, 221112, 221113, 221119, 221121, 221122.
324110.
325181, 325120, 325131, 325182, 211112, 325998, 331311, 325188.
325110, 325132, 325192, 325188, 325193, 325120, 325199.
325520, 325920, 325910, 325182, 325510.
211112.
486210, 221210.
322110, 322121, 322122, 322130.
322121, 322122.
336111, 336112, 336211, 336992, 336322, 336312, 336330, 336340,
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SIC a
Industry group
Pharmaceuticals ........................................................
33839
NAICS b
283
325411, 325412, 325413, 325414.
a Standard
Industrial Classification.
b North American Industry Classification System.
Entities potentially affected by the
subject rule for today’s action also
include State, local, and tribal
governments.
B. How Is This Preamble Organized?
The information presented in this
preamble is organized as follows:
I. General Information
A. What are the regulated entities?
B. How is this preamble organized?
II. Background
III. Today’s Action
A. Three Issues for Which Reconsideration
Was Granted
1. Legal Basis
2. The 20 Percent Replacement Cost
Threshold
3. Revisions to the Format for
Incorporating the PSD FIP into State
Plans
B. Remaining Issues in Petitions for
Reconsideration
1. Petitioners’ claim that EPA retroactively
applied the ERP
2. Petitioners’ claim that EPA cannot
modify a State’s SIP without a finding of
deficiency
IV. Statutory and Executive Order Reviews
A. Executive Order 12866—Regulatory
Planning and Review
B. Paperwork Reduction Act
C. Regulatory Flexibility Act
D. Unfunded Mandates Reform Act
E. Executive Order 13132—Federalism
F. Executive Order 13175—Consultation
and Coordination with Indian Tribal
Governments
G. Executive Order 13045—Protection of
Children from Environmental Health &
Safety Risks
H. Executive Order 13211—Actions That
Significantly Affect Energy Supply,
Distribution, or Use
I. National Technology Transfer and
Advancement Act
J. Congressional Review Act
V. Statutory Authority
VI. Judicial Review
II. Background
On October 27, 2003, we published
the Equipment Replacement Provision
(‘‘ERP’’) amendments to our regulations
implementing the major NSR
requirements of the CAA.1 The ERP
amended the exclusion from major NSR
for ‘‘routine maintenance, repair, and
replacement’’ (‘‘RMRR’’) activities at
existing major sources. Several parties
1 The October 27, 2003 final rule did not act on
the ‘‘Annual Maintenance, Repair and Replacement
Allowance’’ approach that we proposed on
December 31, 2002 (67 FR 80920). We may act on
this portion of the 2002 proposal in a subsequent
rulemaking.
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sought judicial review of the ERP in the
U.S. Court of Appeals for the District of
Columbia Circuit. See State of New York
v. EPA, No. 03–1380 and consolidated
cases (DC Cir.). As a result of a court
order, the ERP is ‘‘stayed’’ (i.e., not in
effect) until the court decides this case.
On December 24, 2003, EPA
published a rule amending the
Prevention of Significant Deterioration
(PSD) provisions of state programs that
did not have approved state rules for
PSD. 68 FR 74483. In each of these
states, EPA previously had made the
area subject to the PSD rules in 40 CFR
52.21, the Federal Implementation Plan
(‘‘FIP’’) for PSD. Please see 68 FR 74483
(December 24, 2003), for additional
background on this rule. Parties have
also sought judicial review of this rule,
and their petitions for review have been
consolidated with the challenges to the
ERP.
Also on December 24, 2003, a group
of environmental organizations 2
petitioned EPA, pursuant to section
307(d)(7)(B) of the CAA, to reconsider
three aspects of the Equipment
Replacement Provision that we
published on October 27, 2003.
Specifically, the petitioners 3 asserted
that our legal basis for the ERP is
flawed, the basis for the 20 percent ERP
cost threshold is arbitrary and
capricious, and EPA has retroactively
applied the ERP.
On January 16, 2004, a subset of the
environmental petitioners on the ERP
rule filed a petition for reconsideration
of the December 24, 2003 rule that
incorporated the ERP into the FIP
portion of a State plan where the State
does not have an approved PSD State
Implementation Plan (SIP). This petition
reiterated the issues raised in the
December 24, 2003 petition concerning
the ERP. On February 23, 2004, a group
of states and the District of Columbia 4
2 The following parties filed the petition for
reconsideration of the October 27, 2003 rule:
Natural Resources Defense Council, Environmental
Defense, Sierra Club, American Lung Association,
Communities for a Better Environment, United
States Public Interest Research Group, Alabama
Environmental Council, Clean Air Council, Group
Against Smog and Pollution, Michigan
Environmental Council, The Ohio Environmental
Council, Scenic Hudson, and Southern Alliance for
Clean Energy.
3 In this notice, the term ‘‘petitioner’’ refers only
to those entities that filed petitions for
reconsideration with EPA.
4 The states that filed a petition for
reconsideration of the December 24, 2003 rule are
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filed a petition for reconsideration of the
December 24, 2003 rule. This petition
raised two issues. First, it asked for
reconsideration on whether EPA needed
to make a finding of deficiency for the
PSD portions of each SIP before it
amended the incorporation of the PSD
FIP into the state plans. Second, it
challenged whether EPA needed to
provide an opportunity for comment on
the revised format for incorporating the
PSD FIP into state plans, which would
automatically update the state plans
whenever EPA amends the PSD FIP.
On July 1, 2004 (69 FR 40278), we
granted reconsideration and requested
comment on three issues raised by
petitioners—specifically, the
contentions that our legal basis is
flawed, that our selection of 20 percent
for the cost limit is arbitrary and
capricious and lacks sufficient record,
and that we should provide an
opportunity for comment on the revised
format for incorporating the PSD FIP
into state plans. We decided to grant
reconsideration on these issues because
of the importance EPA attaches to
ensuring that all have ample
opportunity to comment. At that time,
we did not act on the remaining two
issues in those petitions.
On August 2, 2004, we held a public
hearing on the issues for which we
granted reconsideration. Five
individuals gave oral presentations at
the hearing. The transcript of their
comments is located in Docket OAR–
2002–0068 (Legacy Number A–2002–
04), which can be accessed on the
Internet at https://www.epa.gov/edocket.
The public comment period on the
reconsideration issues ended on August
30, 2004, and we allowed until
September 1, 2004 to receive public
comments for issues arising out of the
August 2nd public hearing. More than
350 written public comments on the
reconsideration issues were received.
The individual comment letters can be
found in Docket OAR–2002–0068
(Legacy Number A–2002–04).
III. Today’s Action
At this time, we are announcing our
final action on reconsideration of the
three issues for which we asked for
comment in our July 1, 2004 notice. We
California, Connecticut, Illinois, Massachusetts,
New Jersey, and New York, along with the District
of Columbia.
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are also announcing our final decision
on the remaining two issues that were
raised by the petitioners. We are making
available a document entitled,
‘‘Technical Support Document for the
Equipment Replacement Provision of
the Routine Maintenance, Repair and
Replacement Exclusion:
Reconsideration,’’ EPA 456/R–05–003.
This document contains (1) a summary
of comments received on the issues for
which we granted reconsideration and
our responses to these comments, and
(2) a summary of petition issues for
which we are not granting
reconsideration, and our rationale for
denying reconsideration. This document
is available on our Web site at https://
www.epa.gov/nsr/; and, through the
National Technical Information
Services, 5285 Port Royal Road,
Springfield, VA 22161; telephone (800)
553–6846, e-mail https://www.ntis.gov;
and, from the U.S. EPA, Library
Services, MD C267–01, Research
Triangle Park, NC 27711, telephone
(919) 541–2777, e-mail
library.rtp@epa.gov.
A. Three Issues for Which
Reconsideration Was Granted
1. Legal Basis
Our July 1, 2004 notice noted that
underlying our legal rationale for the
ERP is a basic tenet of administrative
law stated in Chevron, U.S.A., Inc. v.
NRDC, 467 U.S. 837 (1984). The
Chevron Court held that expert agencies
have the discretion to reasonably
interpret ambiguous statutory terms and
that such interpretations are due
deference. Id. at 842–845. In the October
27, 2003 final rule and in the July 1,
2004 notice, we explained that the
statutory definition of ‘modification,’
CAA 111(a)(4), and, in particular, the
word ‘‘change’’ in the phrase ‘‘any
physical change or change in the
method of operation,’’ is ambiguous.
The word itself is ambiguous, and the
use of ‘‘any’’ as a modifier, in the
context of the statute, simply requires
EPA to include an indeterminate
number of changes as potential
modifications 5 once EPA defines the
ambiguous term ‘‘change.’’ The ERP,
which establishes criteria for
determining what equipment
replacement activities do not constitute
physical changes, is a rational
interpretation of ‘‘physical change’’ in
the definition of ‘‘modification.’’ See 68
FR 61268–61274 for our more detailed
legal support for the ERP.
5 A physical change would be a modification only
if it resulted in a significant emissions increase as
we define the term.
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In granting reconsideration, we
invited comments on several legal
arguments suggested by commenters on
the meaning of the statutory definition
of ‘‘modification.’’ In particular, we
noted that commenters had suggested
that the plain meaning of the
‘‘modification’’ definition required that
functionally equivalent equipment
replacements not be deemed to be
changes and, therefore, be deemed
RMRR. We also noted that other
commenters took the opposite view
about the plain meaning of the statute.
Both sides of this argument cited the
principle from Chevron that where the
statute’s meaning is clear, the agency
must give its meaning effect (the first
step in statutory analysis under
Chevron, or Chevron 1). Some
commenters had argued that only de
minimis exceptions could be allowed
under the statute. Others had pointed
out that a recognized principle of
administrative law allows an agency to
establish ‘‘bright line’’ criteria to reduce
regulatory burden and provide certainty.
We invited comment on these
arguments and any other possible legal
arguments when we granted
reconsideration on the issue of whether
our legal basis in the ERP was flawed.
We received a number of comments
supporting and opposing the legal basis
for our rule. Commenters renewed and
expanded prior arguments that the
definition of ‘‘modification’’ was clear
and either prohibited or compelled
treating like-kind replacements as
physical changes when replacement
resulted in a potential emissions
increase. Some comments, summarized
below, addressed Congressional intent
as construed by courts, provided
specific textual analysis of the
modification definition, and offered
policy objections to the ERP. We discuss
significant comments below and refer
you to the TSD for this action for
additional discussion of comments and
responses.
a. Congressional Intent. Commenters
assert that the ERP is contrary to
Congressional intent and the decision in
Alabama Power v. Costle, 636 F.2d 323
(D.C. Cir. 1979). They characterize the
opinion as holding that Congressional
intent behind the modification
provision was to include any physical
change that increases emissions, even
though it would undoubtedly prove
inconvenient and costly to affected
industries. They cite a portion of the
opinion that declared, ‘‘the term
‘modification’ is nowhere limited to
physical changes that exceed a certain
magnitude.’’ Additionally, they claim
the Court found EPA’s authority to
exempt activity from ‘‘modification’’
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was limited to de minimis activity. Id.
at 400.
We disagree with the commenters’
reading of Alabama Power. Alabama
Power does not directly address whether
like-kind replacements must be deemed
to be physical changes. The Alabama
Power Court addressed an exemption for
physical changes that resulted in an
emissions increase of less than 100 tons.
It is in this context, where the
replacement activity has been conceded
to be a physical change, that the court
states that the modification definition
‘‘is nowhere limited to physical changes
that exceed a certain magnitude.’’
Alabama Power, 636 F.2d at 400. In
context, the ‘‘magnitude’’ language only
addresses the size of the emission
tonnage increase resulting from a
‘‘change,’’ once the activity meets the
definition of a ‘‘change.’’ The Court did
not have before it the question of
whether the phrase ‘‘any physical
change’’ is ambiguous. Contrary to the
commenter’s assertions, the cited
portion of the Alabama Power opinion
discusses a de minimis exemption only
in the context of emission increases and
not in terms of what constitutes a
physical change (‘‘EPA does have the
discretion * * * to exempt from PSD
review some emission increases on
grounds of de minimis or administrative
necessity’’). Id.
Moreover, the Alabama Power Court
also expresses the expectation that
‘‘bubbling’’ (or netting) in calculating
emission increases and an allowance for
physical changes that result in de
minimis increases in emissions ‘‘will
allow for improvement of plants,
technological changes, and replacement
of depreciated capital stock, without
imposing a completely disabling
administrative and regulatory burden.’’
Alabama Power, 636 F.2d at 400.
(emphasis added). Our subsequent
experience has shown that, even with
netting, a definition of ‘‘physical
change’’ as encompassing as that
supported by these commenters is
inadequate to allow for appropriate
replacement of depreciated capital
stock. See ‘‘New Source Review: Report
to the President’’, June 2002 (Docket No.
OAR–2002–0068, Document No. 0004).
It simply is not the case that the
Alabama Power opinion analyzes and
requires the commenters’ encompassing
construction of ‘‘any physical change.’’
Equally important, a narrow
interpretation of ERP as advocated by
commenters would create hurdles for
ensuring that a process operates
reliably, safely, and efficiently, thereby
increasing the likelihood that net
emissions would be higher.
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The commenters point to several
enforcement filings and other EPA
pronouncements prior to promulgation
of the ERP in which we said the
definition of modification was
unambiguous and had broad
application. Furthermore, they note that
we repeatedly recognized that the
structure of the Act demonstrates that
Congress intended grandfathering to be
of limited duration.
We recognize that, prior to
promulgation of the ERP, we had not
specifically asserted that our
interpretation of ‘‘change’’ and the
exclusions from NSR are based on an
exercise of Chevron discretion. In some
instances, such as in a decision of the
Environmental Appeals Board (EAB), In
re: Tennessee Valley Authority, 9 E.A.D.
357 (EAB 2000), and in briefs in various
enforcement-related cases, we had
interpreted ‘‘change’’ such that virtually
all changes, even trivial ones, were
encompassed by the Act. Thus, we
generally had interpreted the exclusion
as being limited to de minimis
circumstances. However, in the ERP we
asserted that EPA does have the
authority to interpret these key terms
through rulemaking. Upon further
consideration of the history of our
actions, the statute, and its legislative
history, we said that we believe a
different view is permissible, and, for
policy reasons discussed in the ERP
final rule, more appropriate. Therefore,
we adopted our Chevron-based
interpretation of the statute
prospectively in the ERP final rule.6
Subsequent to promulgating the ERP,
we filed court papers noting that, as of
the date of the final ERP rule, we
adopted a new interpretation of the
statute. Our position is most clearly
spelled out in a filing we made in
United States v. Illinois Power Co., et
al., Civil Action No. 99–833 (S.D. Ill.)
(‘‘Illinois Power’’). As we stated to the
Illinois Power Court, ‘‘the United States
does not rely on any prior statements
* * * that a very narrow construction of
the ‘‘routine maintenance’’ exemption is
required by the Clean Air Act itself.
6 We noted in the ERP final rule: We have taken
positions in numerous court filings concerning the
proper interpretation and usage of key statutory
terms, such as ‘‘physical change’’ and ‘‘any physical
change.’’ These positions were based on permissible
constructions of the statute of which the regulated
community had fair notice, and correctly reflect the
Agency’s reasonable accommodation of the Clean
Air Act’s competing policies in light of its
experience at the time it adopted the RMRR
exclusion in 1980. The Agency has sought, and has
obtained, deference for its interpretations, and,
notwithstanding today’s adoption of a revised
interpretation of the statute and an expansion of the
RMRR exclusion, the Agency shall continue to seek
deference for those prior interpretations in ongoing
enforcement litigation. 68 FR at 61272, fn 14.
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Instead, the United States will continue
to rely on EPA’s narrow interpretation
of its prior ‘‘routine maintenance’’
exception, which remains applicable to
this action.’’ Illinois Power, Plaintiff’s
Reply to Defendants’ Proposed Findings
of Fact and Conclusions of Law
(Liability Phase) at 5. We no longer
interpret the language or structure of the
NSR provisions of the Act as an
expression of Congress’s intent to limit
‘‘grandfathering’’ through the indirect
means of the ‘‘modification’’ provision
rather than through other provisions
that clearly can reach all existing
sources. See, e.g., CAA section 110 (SIP
provisions); CAA section 112
(hazardous air pollutant provisions);
CAA sections 401–416 (acid rain
provisions).
Finally, one group of commenters
argues that Congress’s decision in 1977
to cross-reference the preexisting
definition of ‘‘modification’’ in CAA
section 111(a)(4) when it adopted the
modification provision for NSR should
have no impact on assessing whether
the terms of the definition are
ambiguous. They cite EPA’s arguments
in our August 2004 brief in State of New
York v. EPA, D.C. Cir. Case No. 02–
1387, which refuted arguments that EPA
is compelled to interpret both the NSPS
and the NSR modification provisions
the same way. They construe the ‘‘legal
basis’’ discussion in our October 27,
2003, ERP final rule as arguing that
Congress ratified our ERP interpretation
when it enacted the 1977 amendments.
We disagree with the characterization
of our argument in the October 27, 2003
preamble to the final ERP rule. Nowhere
in that notice do we argue that Congress
mandated adoption of the 1977 NSPS
regulatory interpretation of what is a
‘‘modification’’ when it cross-referenced
the definition in CAA 111(a)(4) into the
NSR program. As we discussed in the
cited passages of our briefs, we do not
believe Congress intended to ratify the
then-existing interpretation or
‘‘congeal’’ our NSR regulations as they
stood under the NSPS program in 1977.
Our discussion of the history of our
interpretation of CAA 111(a)(4) simply
points out the obvious: that words of
CAA 111(a)(4) historically have been
taken to have quite different meanings
in the NSR and NSPS programs. From
this, we argue that any words that can
be given such divergent meanings for
decades cannot have but one clear
meaning on their face. To argue that the
definition of ‘‘modification’’ in CAA
111(a)(4) is unambiguous, as the
commenters have, one must advance an
unusual position: that the same words,
with no further definitions or legislative
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33841
history, facially and unambiguously
mean different things.
b. Textual analysis of the
modification definition. It is axiomatic
that the most clear expression of what
Congress intended by the
‘‘modification’’ definition is in the
words it chose to use. Many significant
comments we received analyzed the
structure of the definition and particular
words and phrases in it.
One commenter argued that the
statutory term ‘‘modification’’ itself is
not ambiguous, so the definition of
modification should not be read to
create ambiguity in the term. The
commenter, who argued that the ERP is
too generous in excluding equipment
replacements from NSR, observed that
the plain meaning of modification
connotes moderate, as opposed to
fundamental, change.
We disagree with the assertion that
the ERP allows for ‘‘fundamental’’
change in an emission source. In
focusing on the 20 percent criterion of
the ERP, the commenter ignores other
important criteria under the ERP that
would, in any ordinary sense of the
term, prohibit the possibility of
fundamental change as a result of
activities that meet the ERP exclusion.
A source that maintains its basic design
parameters is not fundamentally
changed, nor is a source that replaces
one piece of equipment with another
that is functionally equivalent. Thus,
the ERP does not allow for fundamental
change of the type the commenter
suggests that the term ‘‘modification’’
should prohibit. In fact, to clarify this,
the ERP explicitly precludes activities
that would change the basic design
parameters from qualifying for a RMRR
exclusion.
Moreover, we disagree with the
commenter’s assertion that the term
‘‘modification’’ itself is unambiguous
and in no need of further clarification.
In fact, we note that over the years
permitting authorities have had to
respond to numerous queries regarding
whether certain activities constitute a
‘‘modification,’’ a testament that there is
considerable ambiguity surrounding this
term. Apparently, Congress agrees with
our view, because it supplied further
definition in CAA 111(a)(4).
Many of the comments focused on the
significance of the modifier ‘‘any’’ in
‘‘any physical change or change in the
method of operation.’’ In our October
27, 2003 final rule, we said that the
word ‘‘any’’ did not compel EPA to
define what constitutes a ‘‘physical
change’’ to include all activities that
could conceivably be defined as a
physical change. In our view, we had
discretion to define what activities were
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physical changes, and once we defined
physical change, ‘‘any’’ simply meant
that any activity that met our definition
of physical change could be a
modification if it also increased net
emissions.
In our July 1, 2004 notice, we invited
comment on a recent Supreme Court
case that construed a prohibition on
states and localities enacting legislation
to bar ‘‘any entity’’ from offering
interstate telecommunications services
to not apply to legislation that
restrained political subdivisions of
states from entering the field. Nixon v.
Missouri Municipal League, 541 U.S.
125, 124 S. Ct. 1555, 1559–60 (2004).
The Nixon Court observed that
Congress’s understanding of ‘‘any’’ can
differ depending upon the statutory
setting. Id. at 1561. This opinion
reversed a case litigants had relied upon
in seeking a stay of the ERP on the
proposition for which it was cited.7
In discussing the significance of the
modifier ‘‘any’’ in the statute and in
discussing the Nixon case, commenters
opposed to the ERP argued that
numerous cases besides Nixon have
held that terms modified by the word
‘‘any’’ must be given the most inclusive
meaning possible, that such terms must
be interpreted expansively, and that
‘‘any’’ has a broad meaning.8 These
commenters distinguished Nixon on the
grounds that this case raised peculiar
federalism concerns (i.e., the ability of a
state to regulate its own political
subdivisions) not present in CAA
111(a)(4) or the ERP.
Several other precedents establish
that the principle on which Nixon
relies, that the understanding of ‘‘any’’
can depend on the statutory context, is
not limited to situations with federalism
implications. E.g., O’Connor v. U.S., 479
U.S. 27, 31 (1986) (statutory context
shows ‘‘any taxes’’ limited to taxes of
the Republic of Panama); Mastro
Plastics Corp. v. NLRB, 350 U.S. 270–85
(1956) (‘‘any strike’’ does not include
strike in response to unfair labor
practices); Bell Atlantic Tel. Cos. v. FCC,
131 F.3d 1044, 1047 (D.C. Cir. 1997)
(FCC regulation narrowing ‘‘any * * *
facilities or services’’ that a Bell
7 State and Municipal Petitioners’ Emergency
Motion for a Stay, State of New York v. EPA, D.C.
Cir. No. 03–1380 and consolidated cases, at 8 fn.14
(citing Missouri Mun. League v. FCC, 299 F.3d 949,
954 (8th Cir. 2002), rev’d sub nom. Nixon v.
Missouri Mun. League, 541 U.S. 125, 124 S. Ct. 1555
(2004)). A copy of this motion was submitted to the
record as a comment on the reconsideration notice.
8 E.g., Harrison v. PPG Industries, 446 U.S. 578
(1980); United States v. Gonzales, 520 U.S. 1 (1997);
Department of HUD v. Rucker, 535 U.S. 125 (2002).
A post-Nixon addition to this line of cases is
Norfolk Southern Railway Co. v. James N. Kirby, Pty
Ltd., 125 S. Ct. 385 (2004).
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operating company could offer affirmed
when Court notes ‘‘textual analysis is a
language game played on a field known
as ‘context’’’). Therefore, we believe the
‘‘broader frame of reference’’ adopted by
the Nixon Court is not an isolated and
unsupported view of the law limited to
cases raising federalism concerns.
None of the cases cited by the
commenters stand for the proposition
that a term modified by the word ‘‘any’’
invariably must be given its broadest
meaning. In Harrison and in other cases,
the Court found ‘‘no indication
whatever’’ that Congress intended a
narrower or limited construction of
statutory term. These cases discuss a
different statutory context than the
adoption of the definition of
‘‘modification’’ in the NSR provisions of
the CAA. These cases do not involve a
situation in which Congress
incorporated into a section of a statute
a term that had been used in another
section of the statute and which had
been given a different meaning under
that prior section. While there is no
evidence that Congress compelled EPA
to replicate its NSPS interpretation of
‘‘any physical change’’ in the NSR
program, the fact that the words at issue
were given a different construction in
the NSPS is an indication that the words
do not have a unique and, therefore,
unambiguous meaning.
The cases cited by the petitioners and
the Nixon line of cases are not, in fact,
opposing and contradictory. Both
support looking for indications in the
statute that suggest a more limited
meaning of the modified term is
possible or intended. We believe such
indications exist in the NSR context
because the modification definition
inserted into the NSR provisions by a
1977 technical amendment to the 1977
CAA Amendments cross-referenced the
pre-existing term under CAA 111(a)(4).
Implicitly, at least one of the
commenters critical of the ERP
recognized that a broader frame of
reference can apply by arguing that
while in Nixon, a broad construction of
‘‘any’’ would have led to absurd, futile,
and farfetched results, the same would
not be true for the NSR modification
definition. For NSR, according to the
commenters, Congress placed a clear
limit on what changes must be
considered modifications—those that
increase emissions.
In the definition of ‘‘modification,’’
we believe a view that ‘‘any’’ compels
a broad construction of the modified
terms also has farfetched implications.
The same word ‘‘any’’ that modifies
‘‘physical change in’’ also modifies
‘‘change in the method of operation of.’’
The commenters’ argument proves too
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much. The argument would say that
exemptions from the definition of
modification on any basis other than de
minimis increases would not be
necessary or appropriate, even long
accepted ones that limit the scope of
‘‘change in the method of operation.’’ As
the preamble to the final rule notes,
many of these exemptions can result in
non-de minimis increases in emissions.
68 FR at 61272. To accept the
commenter’s argument would mean that
one word (‘‘change’’) that modifies two
clauses in a definition compels a broad
construction of one modified clause
while allowing discretion when it
modifies the other clause.
Another commenter picks up on
Nixon’s reliance on the doctrine of
avoiding absurd or futile results and
echoes the view that this doctrine
would not apply in the context of the
modification definition. In this
commenter’s view, EPA cannot claim
that a broad construction of ‘‘any
physical change’’ would lead to absurd
or futile results when we adopted such
a broad construction of ‘‘any physical
change’’ in the past and continue to seek
deference for such an interpretation in
ongoing enforcement litigation.
We do not claim our prior
interpretation is absurd or futile. The
Agency claims that the use of the word
‘‘any’’ in the statute does not compel
only our prior interpretation.
We note that under the NSPS
program, we interpreted CAA 111(a)(4)
to allow us to exempt ‘‘[m]aintenance,
repair, and replacement which the
Administrator determines to be routine
for a source category.’’ 40 CFR
60.14(e)(1). In contrast, under the NSR
program, historically we have
interpreted the RMRR provision on a
case-by-case basis, and we have not
followed suit with the NSPS program in
determining that the same activities are
categorically exempt from RMRR. Thus,
a modification that is categorically
exempt under the NSPS could be
potentially subject to NSR under our
historical RMRR interpretation. It would
be incongruous to argue that the
identical statutory text incorporated into
both the NSPS and the NSR provisions
‘‘clearly’’ could support only one
meaning in the NSR context while it
supports a different meaning in the
NSPS context. Rather than saying CAA
111(a)(4) is clear but has two distinct
meanings, common sense suggests the
wording is ambiguous and allows for an
expert agency to adopt reasonable
interpretations in the context of the
programs.
Commenters incorrectly claim that we
have recognized all equipment
replacements, including ‘‘like-kind’’
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replacements, to be ‘‘physical changes’’
within the ordinary meaning of the
word. While our October 27, 2003, final
rule recognized that ‘‘change’’ is
susceptible to multiple meanings, and
outlined many common uses of the
word, we did so to illustrate that there
is no one, unambiguous, common
meaning for the word. That is the
essence of ambiguity.
Several commenters agreed with our
view that ‘‘any’’ should be interpreted
within the ‘‘broader frame of reference’’
of its statutory context. One commenter
argued that Nixon undermined much of
the logic in Wisconsin Electric Power
Co. v. Reilly, 893 F.2d 901 (7th Cir.
1990) (WEPCO). That case contains
sweeping language that repeatedly
stressed that ‘‘any’’ compelled a broad
interpretation of ‘‘any physical change.’’
As we noted in our October 27, 2003
final rule, we believe that the WEPCO
Court was correct to determine that the
statute does not unambiguously allow
all like-kind replacements to avoid NSR,
which was the position advanced by
WEPCO in that litigation and which is
the position advanced in this
reconsideration by certain commenters.
The Court’s conclusion that the statute
does not compel the outcome favored by
WEPCO leads to a result that is
completely consistent with our current
view. Additionally, we continue to
believe that the activities at issue in
WEPCO were not RMRR under the rules
at issue in that case. Furthermore, we
continue to believe that, under the ERP,
the equipment replacements at issue in
that case would not automatically
qualify as being excluded from major
NSR. However, we agree with the
commenter that Nixon calls into
question the additional discussion in
WEPCO that construes ‘‘any’’ to compel
a broad view of what is a ‘‘physical
change.’’ In our view, ‘‘any physical
change’’ is an ambiguous term that can
be defined by the Agency through
rulemaking.
Focusing on a different portion of the
definition of ‘‘modification,’’
commenters argue that Congress
provided the only acceptable limitation
on what physical changes are not
subject to NSR as a modification, which
is the requirement that the physical
change result in an increase in
emissions of any pollutant or the
emission of any pollutant not previously
emitted.9 Commenters argue that an
agency cannot imply an exemption to,
or otherwise insert limiting language
into, a categorical statutory provision,
9 We note that it is to these limitations the
Alabama Power Court said that we could establish
de minimis increase levels.
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especially where Congress was specific
in how it would allow the language to
be limited.
We disagree with the commenters on
three grounds. First, the commenters
seem to assume the answer to the
threshold question—that equipment
replacements that meet the ERP criteria
are ‘‘physical changes’’—in order to say
that we are creating an exemption for
activity that is presumptively subject to
NSR. We believe that there is no such
presumption prior to the agency
defining the ambiguous term. Second,
we believe that the implication of the
commenters’ argument would mean that
several long-accepted exemptions from
NSR would no longer be valid were
their position adopted. These
exemptions from ‘‘any * * * change in
the method of operations’’ were
discussed in our final rule legal basis.
Finally, we believe that the commenters’
argument would not give meaning to all
the words of the definition of
modification. The commenters’ position
reads the ‘‘any physical change or
change in the method of operation’’ to
be so inclusive that essentially the test
for a modification becomes whether
emissions increase at a source because
there always will be some ‘‘change’’ to
which the increase can be linked. In
contrast, the ERP, as part of our overall
approach to the definition of
modification, gives meaning to both the
‘‘change’’ portion as well as the
‘‘emissions increase’’ portion of the
definition.
To summarize: With respect to
existing sources, the purpose of the NSR
provisions is simply to require the
installation of controls at the
appropriate and opportune time. The
kind of replacements that automatically
fall within the equipment replacement
provision established today do not
represent such an appropriate and
opportune time. Accordingly, and given
that it is consistent with the meaning of
‘‘change’’ to treat this kind of
replacement as not being a ‘‘change,’’
we believe excluding them on that basis
from the definition of ‘‘modification’’ as
used in the NSR program is well
calculated to serve all of the policies of
the NSR provisions of the CAA, and is
therefore a legitimate exercise of our
discretion under Chevron, U.S.A. Inc. v.
NRDC, 467 U.S. 837 (1984), to construe
an ambiguous term. Likewise, we
believe this approach is consistent with
the holding in the WEPCO case, and
with some though not all of that case’s
reasoning.
Finally, one comment argued that
EPA’s position on the meaning of
‘‘change’’ is internally inconsistent. If
equipment replacement is not a change,
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then the comment suggests EPA lacks
authority to regulate changes that
exceed 20 percent of the replacement
cost. If equipment replacement is a
change, then the comment suggests that
an exemption can only be justified by de
minimis authority.
We note that establishing bright line
criteria in a manner that reduces
regulatory cost and provide certainty is
a well-recognized and accepted
approach to clarifying ambiguous terms
in statutes. See Time Warner
Entertainment Co. LP v. FCC, 240 F.3d
1126, 1141 (D.C. Cir. 2001). The ERP
simply establishes bright lines for when
an equipment replacement activity is
automatically excluded from major
NSR.
As we explained in our final ERP rule
preamble, this approach is consistent
with our approach towards
‘‘reconstruction’’ in the NSPS context.
Under the NSPS rules, we treat a 50
percent threshold as a trigger for
scrutiny as to whether the source must
meet the NSPS. 40 CFR 60.15(b)(1). We
then assess the technological and
economic feasibility of meeting the
NSPS standard. 40 CFR 60.15(b)(2).
In the ERP, we do not take the
position that all like-kind or
functionally-equivalent replacements
automatically are or are not changes.
Instead, we simply draw criteria for
when such activities are excluded from
NSR and when the multi-factor RMRR
approach applies.
c. Policy objections. Several
comments disputed the manner in
which we exercised our discretion in
defining which equipment replacement
activities are not changes. As noted
below, these comments tended to infer
that we were defeating Congressional
intent through the practical effects of
the ERP.
Some commenters criticize the ERP as
allowing for perpetual immunity from
emissions control requirements. These
commenters claim that the ERP reflects
EPA’s disagreement with Congress’s
determination that the time to install
controls is when a unit is modified. In
the commenters’ opinion, EPA’s belief
that it is not plausible that replacements
would proceed if emissions controls
needed to be installed lacks a factual
basis and is contrary to the statutory
scheme.
Our disagreement over what
constitutes a modification is with the
commenter and not Congress. Major
source NSR permitting is required
unless the source can meet the criteria
of the ERP, is not otherwise exempt
under the RMRR provision or another
NSR exemption or exclusion, and the
source does not accept enforceable
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emissions limit below the significant
emissions increase levels. When a
replacement is a modification under our
clearer, more focused definition, NSR
permitting will apply, consistent with
the Act.
We do not believe, however, the
modification provisions of the CAA
should be interpreted to ensure that all
major facilities either must eventually
trigger NSR or must degrade in
performance, safety, and reliability. In
fact, such an interpretation cannot be
squared with the plain language of the
CAA. An existing source triggers NSR
only if it makes a physical or
operational change that results in an
emissions increase. Thus, a facility can
conceivably continue to operate
indefinitely without triggering NSR—
making as many physical or operational
changes as it desires—as long as the
changes do not result in emissions
increases. This outcome is an
unavoidable consequence of the plain
statutory language and is at odds with
the notion that Congress intended that
every major source would eventually
trigger NSR or otherwise fall into
disrepair. Moreover, there is nothing in
the legislative history of the 1977
Amendments, which created the NSR
program, to suggest that Congress
intended to force all then-existing
sources to go through NSR. To the
extent that some members of Congress
expressed that view during the debate
over the 1990 amendments, such
statements are not probative of what
Congress meant in 1977. Central Bank of
Denver, N.A. v. First Interstate Bank of
Denver, N.A., 511 U.S. 164, 185—86
(1994), and cases cited.
To the extent that our preamble to the
ERP final rule suggested that no
replacements ever would take place if
controls were required, we recognize
that such a generalization is not
established by the record, nor was it our
intent to make such a sweeping
statement. Nevertheless, the substantial
body of testimony and studies in the
record demonstrates that the vagueness
of the RMRR provision operated as a
substantial restraint on replacement
activity even when such activity would
result in safer, more efficient, more
reliable processes that had the potential
to lower emissions in the overall
economy by displacing higher polluting
production. See ‘‘New Source Review:
Report to the President’’, June 2002
(Docket No. OAR–2002–0068,
Document No. 0004). Based on the
record, we believe that an owner or
operator of a source often has the
financial incentive to repair existing
equipment or artificially constrain
production, rather than install emission
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controls. Therefore, as a general matter,
the replacement of that equipment is
not, in fact, an opportune time for the
installation of such controls. It follows
that a policy treating such replacements
as an NSR trigger generally will not lead
to the installation of controls. Rather, it
will merely create incentives to make a
plant less productive than its design
capacity would allow it to be.
These commenters also claim that
Congress intended to strike a different
balance between the nation’s economic
and environmental interests than that
which the ERP strikes. They believe
requiring emission controls on modified
sources would facilitate economic
growth and preserve air quality. They
point out that the 1977 House
Committee report noted, when the
emissions impact of each new or
modified plant is minimized, ‘‘then
more and bigger plants will be able to
locate in the same area without serious
air quality degradation.’’
We agree that we strike the balance
between productive capacity of the
nation and the protection of the
environment differently than these
commenters would. We disagree with
the assertion that the balance we struck
inappropriately weights either
consideration. To the extent that
Congress left discretion to anyone in
striking such a balance, it is afforded to
the Administrator and not to litigants.
The record demonstrates that our
approach, in concert with other CAA
programs, is consistent with preserving
clean air resources and improving air
quality in areas that are not attaining the
NAAQS as well as Congress’s intentions
written explicitly in Sec. 101(b)(1) to
preserve the productive capacity of the
nation’s population and in Sec. 160(3)
to balance economic and environmental
concerns.
When balancing the economic and
environmental interests of the nation,
we have also considered that there are
many other systematic air programs that
will not merely prevent emission
increases from existing sources but even
reduce emissions at sources we expect
to use the ERP. In fact, the entire state
implementation plan (SIP) program
under Sec. 110(a) establishes a
framework for systematic reduction of
emissions from existing sources when
such reductions are deemed necessary
to meet or maintain the NAAQS. The
CAA places primary responsibility on
the States to achieve the emissions
reductions needed to attain and
maintain the NAAQS. Over the years,
States have in fact achieved significant
emissions reductions in furtherance of
this obligation.
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To assist States, we have developed
model market-based programs patterned
after the successful Acid Rain provision
in Title IV of the CAA. For example,
EPA’s recently issued ‘‘Clean Air
Interstate Rule (CAIR),’’ will ensure,
through States adopting a ‘‘cap and
trade’’ or other program approach, that
overall emissions from electric utilities
throughout much of the Eastern part of
the country will meet overall emission
limits that are sharply below that which
they emit today. CAIR ensures that, by
2015, SO2 and NOX emissions will be
permanently reduced by 5.4 million
tons and 2.0 million tons, respectively,
over 2003 levels. Additional emission
reductions will occur after 2015 when
CAIR is fully implemented.
There are other CAA programs, as
well, that are specifically tailored to
require emission reductions from
existing utility and nonutility sources.
These programs include the Maximum
Achievable Control Technology (MACT)
standards that apply to new and existing
sources of air toxics and Control
Technique Guidelines that provide
guidance to states in determining
Reasonably Available Control
Technology (RACT) for sources in ozone
nonattainment areas. All of these CAA
measures will apply systematically to
existing sources, and are unaffected by
the applicability or non-applicability of
any NSR exclusion, such as the RMRR
exclusion and its further definition as
set forth in the ERP. And, in appropriate
circumstances, a State may seek to use
CAA Section 126 to petition for
additional controls on out-of-state
sources.
Even in the absence of these other
CAA programs, we note that the
substitution effect of replacing
deteriorating emission sources with
well-maintained emission sources will
generally reduce emissions per unit of
output. The ERP itself should not
materially affect demand in markets.
Thus, to the extent individual sources
will increase output (and emissions)
following maintenance allowed by the
ERP, output (and emissions) at other
plants will decrease. Thus, we conclude
that the ERP will not lead to an overall
emission increase.
In contrast to the CAA programs
discussed above that systematically and
efficiently obtain emission reductions,
the NSR program for existing sources, as
that program existed before the ERP,
was applied in a scattershot manner,
only triggered by ‘‘modifications’’
however defined on a case-by-case
manner. Under NSR, emissions
reductions can only be obtained in a
‘‘catch-as-catch-can’’ manner, and there
never has been and never can be a date
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certain by which all existing sources in
an area of the country must comply with
an emission cap or a NAAQS. Moreover,
as fully explained in our recent brief
filed in defense of the NSR
Improvements Rule of December 31,
2002, the NSR program is not an
emission reduction program. It is a
program to limit emission increases
resulting from physical and operational
changes. Brief for Respondent at 73–75,
State of New York v. U.S. EPA, No. 02–
1387 & consolidated cases (D.C. Cir.) (‘‘If
Congress had intended to compel
decreases in emissions, it would be
irrational for the requirement to be
triggered only when a facility, in fact,
increases its emissions’’). In light of the
programs under the Act that
systematically and efficiently allow for
both reductions in emissions and firm
caps on emissions, and the scattershot
applicability and limited goals of NSR
program with respect to existing
sources, it was appropriate for us to
strike the balance of economic and
environmental interests in accordance
with the CAA, as we did when we
changed our method for implementing
the modification definition in the NSR
program.
Commenters suggest that EPA’s
decision in promulgating the ERP is not
entitled to deference because, in their
view, it appears that Congress would
not have sanctioned an interpretation
that allows sources to conduct multimillion dollar refurbishment activities
that increase emissions without
triggering NSR. However, the record
establishes that adoption of the ERP will
not cause overall emissions to increase,
while, at the same time, safety,
efficiency, and reliability of plants will
improve. Furthermore, improvements in
safety, efficiency, and reliability
improve environmental performance by
minimizing the frequency of startup,
shutdowns, and malfunctions. While
the record contains some conflicting
data and studies, Congress left the
weighing of this information and the
forming of policies based on this
information to EPA as an expert agency.
We considered the quality and validity
of the submitted data and studies in
developing our conclusions. Our
decisions in this matter are entitled to
deference under Chevron.
2. The 20 Percent Replacement Cost
Threshold
In the December 31, 2002 proposed
rule, EPA solicited comments on the
ERP approach. At that time, we sought
input on a range of possible percentages
of cost that could serve as one of the
criteria that must be met to qualify for
the RMRR exclusion from NSR. We
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asked for comment on percentages
ranging up to 50 percent, the threshold
for reconstruction under the New
Source Performance Standards (NSPS)
program. 67 FR at 80301.
Under the ERP, a project must meet
four separate requirements before it is
automatically excluded from NSR
pursuant to the ERP. The 20 percent
replacement cost threshold is but one of
the four requirements. Thus, projects
that meet the 20 percent threshold are
not exempt from major NSR under the
ERP if they do not meet the other
necessary criteria in the final rule.
These other criteria require that the
replaced component: (1) Be identical or
functionally equivalent; (2) does not
alter the basic design parameters of the
process unit; and (3) does not cause the
process unit to exceed any emission
limitation or operational limitation (that
has the effect of constraining emissions)
that applies to any component of the
process unit and that is legally
enforceable.
Some commenters have asserted that
an equipment replacement project
would be excluded from NSR if it costs
20 percent or less of the replacement
cost of a process unit. However, a
replacement project must meet all four
of the ERP criteria for the ERP to apply.
Thus, only if the replaced component is
(1) identical or functionally equivalent,
(2) does not alter the basic design
parameters of the process unit, and (3)
does not cause the unit to exceed any
emission or operational limit, will the
20 percent criterion be relevant. Of all
of these qualifiers, including the 20
percent cost threshold, the key qualifier
is that the equipment replacement is
‘‘like-kind’’ (i.e., identical or
functionally equivalent). This criterion
provides strong support for our
determination and conclusion that
where the ERP applies, the process unit
has undergone ‘‘no change’’ as a result
of the activity at issue. Thus, the 20
percent cost threshold serves primarily
as an administrative threshold, by
which activities that fall beneath
threshold and which also meet the other
rule criteria safeguards qualify
automatically as RMRR, while those
activities that meet the other criteria but
are over the 20 percent cost threshold
may still be RMRR, but only by applying
the multi-factor RMRR approach.
In the final ERP, we presented policy
arguments and data analyses supporting
20 percent of replacement costs of a
process unit as the threshold cost that
would entitle an equipment
replacement activity (or aggregation of
activities) to qualify automatically as
RMRR, if the other three criteria were
met. See 68 FR 61255–61258. In short,
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33845
we received a substantial amount of
industry data—both from electric
utilities and from other industry
sectors—that supported a decision to set
the threshold at 20 percent. These data
show that many like-kind replacements
occurring at facilities typically cost less
than 20 percent of the process unit’s
value and do not increase emissions. We
also conducted case studies on a
number of industries, analyzed the costs
involved in the Wisconsin Electric
Power Company v. Reilly (‘‘WEPCO’’)
case (See 893 F.2d 901 (7th Cir. 1990))
and other relevant information, and
provided a legal basis as to why 20
percent is a reasonable ERP cost
threshold for equipment replacements
across all industries. We also stipulated
other rule criteria which must be met to
qualify for the ERP. The ERP allows
sources to know, with certainty, that
RMRR can be conducted without delay
in situations where the 20 percent
replacement cost criterion and other
specified criteria are met.
Petitioners asked EPA to reconsider
the 20 percent cost threshold, and
claimed that none of EPA’s arguments
supporting the threshold had appeared
in the proposed rule. We granted
reconsideration on this issue and
solicited additional comment on the
data, our analyses, and the policy
considerations supporting the 20
percent threshold. We also invited
comment on whether it is appropriate to
consider approaches used by local
governments in determining
construction building code applicability
when establishing criteria for RMRR
determinations.
Thus, our goal in selecting the cost
threshold is not to create a bright line
below which any activity is excluded
solely based on its cost. Rather, the
threshold is intended to operate in
combination with the three other ERP
criteria as a screen for determining
when the multi-factor RMRR approach
is applicable and when it is appropriate
to automatically exclude an activity as
RMRR based on satisfying the three noncost ERP criteria. As discussed below,
we continue to believe that 20 percent
is an appropriate threshold for this
purpose. The available data indicate
that the 20 percent threshold will
effectively identify those more
significant projects for which applying
the multi-factor RMRR approach is
prudent.
Another important factor of the ERP is
that related activities must be aggregated
in the same way as they would have to
be aggregated for other NSR
applicability purposes. Under our
current policy of aggregation, two or
more replacement activities that occur
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at different times are not automatically
considered separate activities solely
because they happen at different times.
In the case of replacing an entire
facility, it is not feasible that an owner
or operator could successfully argue that
multiple projects occurring one after the
other are not related to one another and
should not be aggregated for
applicability purposes. These other rule
criteria play an important part in
determining what replacements can
qualify for the ERP.
Much of the comment on the 20
percent replacement value threshold
focused on our use of six non-utility
case studies that we believe support our
selection of a 20 percent replacement
value threshold. Though equipment
replacement activities vary widely
across industry sectors, the six industry
sector studies (pulp and paper mills,
automobile manufacturing, natural gas
transmission, carbon black
manufacturing, pharmaceutical
manufacturing, and petroleum refining)
indicated that equipment replacement
activities of the type allowed under the
ERP generally do not cause increases in
actual emissions. Additionally, though
the six studies address specific case
examples from only a part of regulated
industry, the data indicated that most
typical replacement activities fall within
the 20 percent threshold, and that some
major replacement activities will cross
the 20 percent threshold and be subject
to the multi-factor RMRR approach.
We received a number of comments
through the reconsideration process that
were supportive of the calculations
performed in the case studies of the six
industries. Many of these comments
came from the trade groups representing
industries that were analyzed in the
case studies. These organizations—
including the American Forest & Paper
Association, Alliance of Automobile
Manufacturers, National Petrochemical
& Refiners Association, and Interstate
Natural Gas Association of America—
supported the analyses conducted and
conclusions reached in the case studies
for each of their industries. In some
cases, these trade groups provided
further amplification of their cost ranges
for projects, which provided additional
depth and support to the conclusions of
the report. Other commenters stated that
the case studies failed to provide
sufficient data to support the 20 percent
cost threshold.
We never claimed that the case
studies encompassed all equipment
replacement activities at these
industries. Further, we recognize that
the case studies do not justify
exempting all ‘‘routine’’ equipment
replacement activity in any one of the
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case study industries. As discussed
elsewhere in this notice, activities
falling below the 20 percent
replacement value threshold are not
exempt under the ERP if they do not
meet the other three criteria of the rule.
It is important to note that the case
studies were performed prior to
decisions on the exact form and content
of the final rule. If the studies had
chosen a different set of assumptions
(e.g., for costing of projects, or in
defining the process unit), they may
have identified additional equipment
replacement projects exceeding 20
percent in cost. Furthermore, these
studies showed industry-wide results,
not plant-specific determinations.
Under the ERP, if a plant-specific
replacement activity does not satisfy all
four of the criteria that must be met to
qualify for the RMRR exclusion, then
the activity is subject to the multi-factor
RMRR approach. The studies indicate
that larger, less frequent maintenance
activities could exceed the ERP cost
threshold and, consequently, would be
subject to the multi-factor RMRR
approach.10 Thus, we do not believe
there is a basis, nor did the petitioners
provide one, that all equipment
replacements in these industries would
be exempt under a 20 percent cost
threshold.
We continue to believe that this
information on other industrial sectors
beyond electric utilities supports our 20
percent bright line test. In short, the
case studies support our view that it is
reasonable to assume that equipment
replacement activities in the utility
industry are similar enough to
replacement practices in other industry,
such that the 20 percent value
determined for utilities is appropriate
for industry as a whole.
While most industry commenters
agreed that the 20 percent threshold was
adequate and reasonable and was well
supported by available data, several
industry commenters provided
additional data as further support that
the 20 percent threshold is appropriate.
For example, Solar Turbines estimates
for their products (turbines of 1 to 14
megawatts in capacity), a periodic
refurbishing of the gas producer unit—
normally performed every 4 years—
would cost 6 to 14 percent of the
replacement cost, depending on the
extent of deterioration. The Gas Turbine
Association noted that the restoration
cost as a percentage of total equipment
10 As the Alliance of Automobile Manufacturers
appointed out in their comment letter, despite the
claims of the petitioners, the Abt Study did
consider typical replacement project for their
industry that exceeded the 20 percent cost
threshold.
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replacement cost varies significantly
with turbine unit size. According to the
Gas Turbine Association, one supplier
estimated a range from 9 percent for a
combined cycle system to over 20
percent for a simple cycle system. Other
commenters—including the National
Petrochemical & Refiners Association
and the American Forest & Paper
Association—further supported the 20
percent equipment replacement cost
threshold providing lists of their plant
maintenance activities, many of which
were beneath 20 percent in cost, and
explained why they felt that their listed
projects are routine. We have evaluated
the projects described by commenters
and, assuming that they would meet all
other criteria of the ERP, these projects
would not be the types of activities that
would be subject to the multi-factor
RMRR approach.
We should note, however, that by
referring to these lists provided by
industry, we are not categorically
determining that these activities are
RMRR. As we have explained above, the
20 percent threshold is only one part of
the ERP. Therefore, each activity must
be evaluated against not only the 20
percent cost threshold but also the other
three rule criteria before making a
determination that these activities are
RMRR under the ERP.
Comments filed by the State and
Territorial Air Pollution Program
Administrators (STAPPA) and the
Association of Local Air Pollution
Control Officials (ALAPCO) suggested
that we reject the percent threshold
approach and replace it with a list of
RMRR activities, along with a list of
projects that are not RMRR, for each
major industrial sector. Prior to
promulgating the ERP, we evaluated
developing a list of activities that are
considered RMRR as a component of an
overall RMRR program. Although it was
decided that we could develop a list for
industry sectors for which we had
ample amounts of information, we
believe that there are too many activities
in too many industries, and an excessive
number of facility-specific particulars,
to effectively improve major NSR
implementation by creating such lists.
We also were concerned that such lists
would need to be updated often.
We believe the ERP provides more
clarity than does the multi-factor
approach that permitting authorities
employed in making past RMRR
determinations. With the multi-factor
RMRR approach, no ‘‘bright lines’’ were
ever established, either through rule or
guidance, to evaluate the factors (e.g.,
nature/extent, purpose, frequency and
cost), which contributed to regulatory
uncertainty. Conversely, to the greatest
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extent possible, the ERP provides
‘‘bright lines’’ by specifying criteria that
must be met to qualify as RMRR. Of
course, even with the ERP, there will be
times when a permitting authority must
make judgment calls, such as over
whether the process unit’s basic design
parameters will change as a result of the
equipment replacement. However, we
believe that the ERP will enable these
sorts of decisions to be more limited to
engineering judgments and, therefore,
less contentious (and more uniform
from jurisdiction-to-jurisdiction) than
the decisions required under the multifactor test.
The EPA continues to believe that our
basis for selection of the 20 percent
replacement cost of the process unit is
not arbitrary and capricious, and that
there is support in both the rulemaking
record and preamble for the 20 percent
replacement cost threshold. Considering
all of this information, together with the
additional supporting data provided by
commenters in response to the
reconsideration issues, we believe our
decision to establish the cost threshold
at 20 percent is strongly supported and
persuades us that we have established
the correct cost threshold for the ERP.
future updates to federal PSD
requirements. It will reduce the
potential for confusion when the PSD
rules are updated and will ensure that
the relevant federal provisions are
included in updated PSD FIPs in a
consistent and efficient manner.
3. Revisions to the Format for
Incorporating the PSD FIP Into State
Plans
As discussed above, the December 24,
2003 final rule revised the PSD
provision in each state plan that lacked
an approved state regulation concerning
PSD. In lieu of an approved PSD SIP,
each of these state plans contained a
reference incorporating the relevant
provisions of 40 CFR 52.21, the PSD
FIP, that applied within the state. Prior
to the December 24th rule, we
incorporated the relevant paragraphs of
40 CFR 52.21 by referring to the range
of paragraphs from the first paragraph
incorporated to the last paragraph. This
format required updates every time we
added paragraphs to section 52.21. The
December 24th rule adopted a different
cross-referencing format—‘‘40 CFR
52.21 except paragraph (a)(1).’’ Under
the new format, the cross-references
would automatically update whenever
new sections were added to the PSD
FIP.
We granted reconsideration and
solicited comment on the issue of the
new format and its ability to
automatically update affected state
plans whenever EPA modifies the PSD
FIP. We did not receive comments in
opposition of this new format and thus
will not change it. We believe the
automatic update function will
eliminate paperwork delays and
typographical errors associated with
1. Petitioners’ Claim That EPA
Retroactively Applied the ERP
Petitioners’ claimed that EPA
retroactively applied the ERP, citing an
EPA official’s announcement in
November 2003 that the Agency would
no longer pursue past RMRR violations
if the cases had not been filed. In
response, we are, and have been,
pursuing all filed cases and will
continue to file new cases as
appropriate. Our decisions on which
cases to file is guided by a myriad of
factors, including available resources
and environmental protection. We
acknowledge that the ERP is stayed and
not currently effective in any
jurisdiction. We continue to request
information and put violators on notice
when they violate our rules and
policies. We note that none of the ERP
rule revisions apply to any changes that
are the subject of existing enforcement
actions that the Agency has brought and
none constitute a defense thereto.
As discussed in the final ERP
preamble (68 FR 61263), according to
the U.S. Supreme Court, an agency may
not promulgate retroactive rules absent
express congressional authority. See
Bowen v. Georgetown Univ. Hosp., 488
U.S. 204, 208, 102 L. Ed. 2d 493, 109 S.
Ct. 468 (1988). The CAA contains no
such expressed grant of authority, and
we do not intend by our actions today
to create retroactive applicability to the
ERP. The promulgated ERP applies only
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B. Remaining Issues in Petitions for
Reconsideration
We denied two issues contained in
petitioners’ requests for reconsideration
because they failed to meet the standard
for reconsideration under section
307(d)(7)(B) of the CAA. Specifically, on
these issues, the petitioners have failed
to show: That it was impracticable to
raise their objections during the
comment period, or that the grounds for
their objections arose after the close of
the comment period; and/or that their
concern is of central relevance to the
outcome of the rule. We discuss our
reasons for denying reconsideration in
the Technical Support Document,
which is available on our Web site at
https://www.epa.gov/nsr. We have
concluded that no clarifications to the
underlying rules are warranted for these
two remaining issues, as described
below.
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33847
to conduct that occurs after the rule is
effective.
2. Petitioners’ Claim That EPA Cannot
Modify a State’s SIP Without a Finding
of Deficiency
Petitioners’ opposed the provisions in
our FIP rule published on December 24,
2003, stating that EPA doesn’t have the
authority to issue a FIP without a
finding of deficiency or notice of such
deficiency as required under section
110(k)(5), 42 U.S.C. 7410(k)(5). They
noted that, in order to require a State to
revise its SIP, the EPA must find that a
SIP is ‘‘inadequate to attain or maintain
the relevant national ambient air quality
standard, to mitigate adequately the
interstate pollution described in section
7506a of this title or section 7511c of
this title, or to otherwise comply with
any requirement of this chapter.’’ They
further noted that EPA can only require
a SIP revision upon the finding that a
particular SIP is deficient.
We are not issuing a new FIP. Rather,
we are modifying an existing FIP. As
such, the original findings of
inadequacy of the plans for states
subject to the PSD FIP continue to apply
because these states never submitted an
approvable PSD program in the first
place, or have not submitted a revised
program since EPA’s disapproval of
their earlier submission. Our
longstanding procedure has been to
incorporate § 52.21 into the applicable
implementation plan for a state where
there is no approved, SIP-based,
permitting program. In every PSD
rulemaking since the program’s
inception, we have incorporated all
provisions of the promulgated rules into
the applicable implementation plan for
a state where there is no approved, SIPbased, permitting program. (See 68 FR
11317–11318.) We again are taking these
actions in the case of the December 24,
2003 rules.
As a result, we fail to see how the
petitioning states were not clearly on
notice about our intentions for these
portions of the rule. Thus, EPA believes
states subject to the PSD FIP had
adequate notice and opportunity for
comment that EPA planned to amend
the FIP citations to § 52.21 to reflect any
changes EPA made to § 52.21 in the
final NSR rule. Therefore, the
petitioners have failed to meet the
procedural requirement for
reconsideration. Moreover, EPA does
not believe it makes sense for states
subject to the PSD FIP to have the
option to pick what portions of the FIP
should apply—these states are free to
submit PSD programs for approval as
SIP revisions if they wish to apply
something other than § 52.21 in its
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entirety (although we are making no
conclusion about the approvability of a
program that does not include all the
elements of § 52.21 at this time).
Therefore, even if the petitioners had
been correct that a procedural error had
occurred in this instance, the outcome
would not have been of central
relevance to the outcome of the rule.
It is inherent in the regulatory nature
of a FIP that we retain the authority to
make appropriate changes to the Federal
Program and that these changes will
automatically apply in any jurisdiction
in which the Federal FIP applies
whether or not we delegate authority to
a State to implement the PSD FIP. We
believe that the ERP improves the
ability of a State to ‘‘attain or maintain
the relevant NAAQS, or to mitigate
adequately the interstate pollution
transport.’’ As noted in the preamble to
the final ERP (68 FR 61255), nothing in
the promulgated ERP would prevent a
State or local program from imposing
additional requirements necessary to
meet Federal, State or local air quality
goals.
IV. Statutory and Executive Order
Reviews
A. Executive Order 12866—Regulatory
Planning and Review
Under Executive Order 12866 (58 FR
51735, October 4, 1993), the Agency
must determine whether the regulatory
action is ‘‘significant’’ and therefore
subject to Office of Management and
Budget (OMB) review and the
requirements of the Executive Order.
The Order defines ‘‘significant
regulatory action’’ as one 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;
(2) Create a serious inconsistency or
otherwise interfere with an action taken
or planned by another agency;
(3) Materially alter the budgetary
impact of entitlements, grants, user fees,
or loan programs, or the rights and
obligations of recipients thereof; or
(4) Raise novel legal or policy issues
arising out of legal mandates, the
President’s priorities, or the principles
set forth in the Executive Order.
Pursuant to the terms of Executive
Order 12866, EPA determined that this
rule is a ‘‘significant regulatory action’’
within the meaning of the Executive
Order. As such, EPA has submitted this
action to OMB for review. Changes
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made in response to OMB suggestions or
recommendations will be documented
in the public record.
B. Paperwork Reduction Act
The information collection
requirements (ICR) for this rule have
been prepared under the Paperwork
Reduction Act, 44 U.S.C. 3501 et seq.
The EPA has deferred submission of the
ICR to Office of Management and
Budget (OMB) pending judicial review
of the ERP. An ICR document has been
prepared by EPA (ICR No. 1230.14), and
a copy may be obtained from Susan
Auby, U.S. Environmental Protection
Agency, Office of Environmental
Information, Collection Strategies
Division (2822T), 1200 Pennsylvania
Avenue, NW., Washington, DC 20460–
0001, by e-mail at auby.susan@epa.gov,
or by calling (202) 566–1672. A copy
may also be downloaded off the Internet
at https://www.epa.gov/icr. The
information requirements included in
ICR No. 1230.14 are not enforceable
until OMB approves them.
The information that ICR No. 1230.14
covers is required for the submittal of a
complete permit application for the
construction or modification of all major
new stationary sources of pollutants in
attainment and nonattainment areas, as
well as for applicable minor stationary
sources of pollutants. This information
collection is necessary for the proper
performance of EPA’s functions, has
practical utility, and is not
unnecessarily duplicative of
information we otherwise can
reasonably access. We have reduced, to
the extent practicable and appropriate,
the burden on persons providing the
information to or for EPA. In fact, we
feel that this rule will result in less
burden on industry and reviewing
authorities since it streamlines the
process of determining whether a
replacement activity is RMRR.
However, according to ICR No.
1230.14, we do anticipate an initial
increase in burden for reviewing
authorities as a result of the rule
changes, to account for revising state
implementation plans to incorporate
these rule changes. As discussed above,
we expect those one-time expenditures
to be limited to $580,000 for the
estimated 112 affected reviewing
authorities. For the number of
respondent reviewing authorities, the
analysis uses the 112 reviewing
authorities count used by other
permitting ICR’s for the one-time tasks
(for example, SIP revisions).
Burden means the total time, effort, or
financial resources expended by persons
to generate, maintain, retain, or disclose
or provide information to or for a
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Federal agency. This includes the time
needed to review instructions; develop,
acquire, install, and utilize technology
and systems for the purpose of
responding to the information
collection; adjust existing ways to
comply with any previously applicable
instructions and requirements; train
personnel to respond to a collection of
information; search existing data
sources; complete and review the
collection of information; and transmit
or otherwise disclose the information.
An agency may not conduct or
sponsor, and a person is not required to
respond to a collection of information
unless it displays a currently valid OMB
control number. The OMB control
numbers for EPA’s regulations in 40
CFR are listed in 40 CFR part 9. When
this ICR is approved by OMB, the
Agency will publish a technical
amendment to 40 CFR part 9 in the
Federal Register to display the OMB
control number for the approved
information collection requirements
contained in this final rule.
C. Regulatory Flexibility Act
The EPA has determined that it is not
necessary to prepare a regulatory
flexibility analysis in connection with
this final rule.
For purposes of assessing the impacts
of today’s rule on small entities, small
entity is defined as: (1) A small business
as defined by the Small Business
Administration’s 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, EPA has concluded that this
action will not have a significant
economic impact on a substantial
number of small entities. In determining
whether a rule has a significant
economic impact on a substantial
number of small entities, the impact of
concern is any significant adverse
economic impact on small entities,
since the primary purpose of the
regulatory flexibility analyses is to
identify and address regulatory
alternatives ‘‘which minimize any
significant economic impact of the
proposed rule on small entities.’’ 5
U.S.C. 603 and 604. Thus, an agency
may conclude that a rule will not have
a significant economic impact on a
substantial number of small entities if
the rule relieves regulatory burden, or
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otherwise has a positive economic effect
on all of the small entities subject to the
rule.
We believe this final rule will reduce
the regulatory burden associated with
the major NSR program for all sources,
including all small businesses, by
improving the operational flexibility of
owners and operators, improving the
clarity of requirements, and providing
alternatives that sources may take
advantage of to further improve their
operational flexibility. We have
therefore concluded that today’s final
rule will relieve regulatory burden for
all affected small entities.
D. Unfunded Mandates Reform Act
Title II of the Unfunded Mandates
Reform Act of 1995 (UMRA), Pub. L.
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 the UMRA,
EPA generally must prepare a written
statement, including a cost-benefit
analysis, for proposed and 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 in any 1 year. Before
promulgating an EPA rule for which a
written statement is needed, section 205
of the UMRA generally requires EPA to
identify and consider a reasonable
number of regulatory alternatives and
adopt the least costly, most costeffective or least burdensome alternative
that achieves the objectives of the rule.
The provisions of section 205 do not
apply when they are inconsistent with
applicable law. Moreover, section 205
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 as to 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 the 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 proposals with significant
Federal intergovernmental mandates,
and informing, educating, and advising
small governments on compliance with
the regulatory requirements.
We have determined that today’s rule
does not contain a Federal mandate that
may result in expenditures of $100
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million or more for State, local, and
tribal governments, in the aggregate, or
the private sector in any 1 year. The
change in this rule is expected to result
in a small decrease in the burden
imposed upon reviewing authorities in
order for them to be included in the
State’s SIP, as well as other small
increases in burden discussed under
‘‘Paperwork Reduction Act.’’ In
addition, we believe this final rule will
actually reduce the regulatory burden
associated with the major NSR program
by improving the operational flexibility
of owners and operators, and improving
the clarity of requirements. Thus,
today’s action is not subject to the
requirements of sections 202 and 205 of
the UMRA.
For the same reasons stated above, we
have determined that today’s action
contains no regulatory requirements that
might significantly or uniquely affect
small governments. Thus, today’s action
is not subject to the requirements of
section 203 of the UMRA.
E. Executive Order 13132—Federalism
Executive Order 13132, entitled
‘‘Federalism’’ (64 FR 43255, August 10,
1999), 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.’’
This final rule does not have
federalism implications. It 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. Thus, Executive
Order 13132 does not apply to this rule.
Nonetheless, EPA did consult with
representatives of state and local
governments in developing this rule,
through face-to-face consultations and
through soliciting comment from State
and local officials in our July 1, 2004
Federal Register notice.
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
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33849
to develop an accountable process to
ensure ‘‘meaningful and timely input by
tribal officials in the development of
regulatory policies that have tribal
implications.’’ Today’s final action does
not have tribal implications as specified
in Executive Order 13175. This action
will benefit permitting authorities and
the regulated community, including any
major source owned by a tribal
government or located in or near tribal
land, by providing increased certainty
as to making RMRR determinations
within the NSR program. Thus,
Executive Order 13175 does not apply
to this action.
G. Executive Order 13045—Protection of
Children From Environmental Health
Risks and Safety Risks
Executive Order 13045, entitled
‘‘Protection of Children from
Environmental Health Risks and Safety
Risks’’ (62 FR 19885, April 23, 1997),
applies to any rule that: (1) is
determined to be ‘‘economically
significant’’ as defined under Executive
Order 12866; and (2) concerns an
environmental health or safety risk that
EPA has reason to believe may have a
disproportionate effect on children. If
the regulatory action meets both criteria,
the Agency must evaluate the
environmental health or safety effects of
the planned rule on children, and
explain why the planned regulation is
preferable to other potentially effective
and reasonably feasible alternatives
considered by the Agency.
Today’s action is not subject to the
Executive Order because it is not
economically significant as defined in
Executive Order 12866, and because the
Agency does not have reason to believe
the environmental health or safety risks
addressed by this action present a
disproportionate risk to children. We
believe that today’s action as a whole
will result in equal or better
environmental protection than provided
by earlier regulations, and do so in a
more streamlined and effective manner.
As a result, today’s final rule is not
expected to present a disproportionate
environmental health or safety risk for
children.
H. Executive Order 13211—Actions
Concerning Regulations That
Significantly Affect Energy Supply,
Distribution, or Use
Today’s action is not a ‘‘significant
energy action’’ as defined in Executive
Order 13211, ‘‘Actions Concerning
Regulations That Significantly Affect
Energy Supply, Distribution, or Use’’ (66
FR 28355, May 22, 2001) because it is
not likely to have a significant adverse
E:\FR\FM\10JNR1.SGM
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Federal Register / Vol. 70, No. 111 / Friday, June 10, 2005 / Rules and Regulations
effect on the supply, distribution, or use
of energy.
Today’s rule improves the ability of
sources to maintain the reliability of
production facilities, and effectively
utilize and improve existing capacity.
V. Statutory Authority
I. National Technology Transfer and
Advancement Act
VI. Judicial Review
Section 12(d) of the National
Technology Transfer and Advancement
Act of 1995 (NTTAA), Pub. L. No. 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 (for example,
materials specifications, test methods,
sampling procedures, and business
practices) that are developed or adopted
by voluntary consensus standards
bodies. The NTTAA directs EPA to
provide Congress, through OMB,
explanations when the Agency decides
not to use available and applicable
voluntary consensus standards.
Today’s action does not involve
technical standards. Therefore, EPA did
not consider the use of any voluntary
consensus standards.
J. Congressional Review Act
The Congressional Review Act (CRA),
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 808 allows
the issuing agency to make a rule
effective sooner than otherwise
provided by the CRA if the agency
makes a good cause finding that notice
and public procedure is impracticable,
unnecessary or contrary to the public
interest. This determination must be
supported by a brief statement. 5 U.S.C.
808(2). As stated previously, EPA has
made such a good cause finding,
including the reasons therefor, and
established an effective date of June 10,
2005. EPA will submit a report
containing this rule and other required
information to the U.S. Senate, the U.S.
House of Representatives, and the
Comptroller General of the United
States prior to publication of the rule in
the Federal Register. This action is not
a ‘‘major rule’’ as defined by 5 U.S.C.
804(2).
VerDate jul<14>2003
16:23 Jun 09, 2005
Jkt 205001
The statutory authority for this action
is provided by sections 101, 111, 114,
116, 301, and 307 of the CAA as
amended (42 U.S.C. 7401, 7407, 7411,
7414, 7416, and 7601).
Under section 307(b)(1) of the Act, the
opportunity to file a petition for judicial
review of the October 27, 2003 final rule
or the December 24, 2003 final rule has
passed. Judicial review of today’s final
action is available only by the filing of
a petition for review in the U.S. Court
of Appeals for the District of Columbia
Circuit by August 9, 2005. Any such
judicial review is limited to only those
objections that are raised with
reasonable specificity in timely
comments. Under section 307(b)(2) of
the Act, the requirements that are the
subject of the October 27, 2003 and
December 24, 2003 final rules and
today’s final action may not be
challenged later in civil or criminal
proceedings brought by us to enforce
these requirements.
List of Subjects in 40 CFR Parts 51 and
52
Environmental protection,
Administrative practices and
procedures, Air pollution control,
Intergovernmental Relations, New
source review, Prevention of significant
deterioration, Routine maintenance,
repair and replacement, Equipment
replacement.
Dated: June 6, 2005.
Stephen L. Johnson,
Administrator.
[FR Doc. 05–11546 Filed 6–9–05; 8:45 am]
BILLING CODE 6560–50–P
ENVIRONMENTAL PROTECTION
AGENCY
40 CFR Part 52
[R03–OAR–2005–PA–0013; FRL–7923–4]
Approval and Promulgation of Air
Quality Implementation Plans;
Pennsylvania; VOC and NOX RACT
Determinations for Seven Individual
Sources
Environmental Protection
Agency (EPA).
ACTION: Proposed rule.
AGENCY:
SUMMARY: EPA proposes to approve
revisions to the Commonwealth of
Pennsylvania State Implementation Plan
(SIP). The revisions were submitted by
the Pennsylvania Department of
Environmental Protection (PADEP) to
PO 00000
Frm 00054
Fmt 4700
Sfmt 4700
establish and require reasonably
available control technology (RACT) for
seven major sources of volatile organic
compounds (VOC) and nitrogen oxides
(NOX) pursuant to the Commonwealth
of Pennsylvania’s (Pennsylvania or the
Commonwealth) SIP-approved generic
RACT regulations. EPA is proposing to
approve these revisions in accordance
with the Clean Air Act (CAA).
DATES: Written comments must be
received on or before July 11, 2005.
ADDRESSES: Submit your comments,
identified by Regional Material in
EDocket (RME) ID Number R03–OAR–
2005–PA–0013 by one of the following
methods:
Federal eRulemaking Portal: https://
www.regulations.gov. Follow the on-line
instructions for submitting comments.
Agency Web site: https://
www.docket.epa.gov/rmepub/. RME,
EPA’s electronic public docket and
comment system, is EPA’s preferred
method for receiving comments. Follow
the on-line instructions for submitting
comments.
E-mail: campbell.dave@epa.gov.
Mail: R03–OAR–2005–PA–0013,
David Campbell, Chief, Air Quality
Planning Branch, Mailcode 3AP21, U.S.
Environmental Protection Agency,
Region III, 1650 Arch Street,
Philadelphia, Pennsylvania 19103.
Hand Delivery: At the previouslylisted EPA Region III address. Such
deliveries are only accepted during the
Docket’s normal hours of operation, and
special arrangements should be made
for deliveries of boxed information.
Instructions: Direct your comments to
RME ID No. R03–OAR–2005–PA–0013.
EPA’s policy is that all comments
received will be included in the public
docket without change, and may be
made available online at https://
www.docket.epa.gov/rmepub/,
including any personal information
provided, unless the comment includes
information claimed to be Confidential
Business Information (CBI) or other
information whose disclosure is
restricted by statute. Do not submit
information that you consider to be CBI
or otherwise protected through RME,
regulations.gov or e-mail. The EPA RME
and the Federal regulations.gov Web
sites are an ‘‘anonymous access’’
system, which means EPA will not
know your identity or contact
information unless you provide it in the
body of your comment. If you send an
e-mail comment directly to EPA without
going through RME or regulations.gov,
your e-mail address will be
automatically captured and included as
part of the comment that is placed in the
public docket and made available on the
E:\FR\FM\10JNR1.SGM
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Agencies
[Federal Register Volume 70, Number 111 (Friday, June 10, 2005)]
[Rules and Regulations]
[Pages 33838-33850]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: 05-11546]
=======================================================================
-----------------------------------------------------------------------
ENVIRONMENTAL PROTECTION AGENCY
40 CFR Parts 51 and 52
[FRL-7923-3; E-Docket ID No. OAR-2002-0068]
RIN 2060-AM58
Prevention of Significant Deterioration (PSD) and Non-attainment
New Source Review (NSR): Equipment Replacement Provision of the Routine
Maintenance, Repair and Replacement Exclusion: Reconsideration
AGENCY: Environmental Protection Agency (EPA).
ACTION: Notice of final action on reconsideration.
-----------------------------------------------------------------------
SUMMARY: On October 27, 2003, and December 24, 2003, the EPA revised
regulations governing the major New Source Review (NSR) programs
mandated by parts C and D of title I of the Clean Air Act (CAA or Act).
The rule changes from October 27, 2003, provide a category of equipment
replacement activities that are deemed to be routine maintenance,
repair and replacement (RMRR) activities and, therefore, are not
subject to Major NSR requirements under the exclusion, while the
December 24, 2003 rule changes amended the Prevention of Significant
Deterioration (PSD) provisions of state programs that did not have
approved state rules for PSD. Also on December 24, 2003, the U.S. Court
of Appeals for the District of Columbia Circuit stayed the new RMRR
rules, pending judicial review. Following these actions, the
Administrator received petitions for reconsideration. On July 1, 2004,
we, the EPA, announced our reconsideration of certain issues arising
from these two final rules and requested comment on those issues. After
carefully considering all of the comments and information received
through our reconsideration process, we have concluded that no
additional changes are necessary to the final rules. With respect to
all other issues raised by the petitioners, we deny the requests for
reconsideration.
DATES: This final action is effective on June 10, 2005.
ADDRESSES: EPA has established a docket for this action under Docket ID
No. OAR-2002-0068 (Legacy Number A-2002-04). All documents in the
docket are listed in the index. Although listed in the index, some
information is not publicly available, i.e., CBI or other information
whose disclosure is restricted by statute. Publicly available docket
materials are available in hard copy either electronically in the
EDOCKET at https://www.epa.gov/edocket or in hard copy at the U.S.
Environmental Protection Agency, EPA West (Air Docket), 1200
Pennsylvania Avenue, Northwest, B102, Mail code: 6102T, Washington, DC
20460, Attention Docket ID No. OAR-2002-0068, Washington, DC 20004. The
Public Reading Room is open from 8:30 a.m. to 4:30 p.m., Monday through
Friday, excluding legal holidays. The telephone number for the Public
Reading Room is (202) 566-1744, and the telephone number for the Docket
is (202) 566-1742.
FOR FURTHER INFORMATION CONTACT: Mr. David J. Svendsgaard, Information
Transfer and Program Integration Division (C339-03), U.S. Environmental
Protection Agency, Research Triangle Park, NC 27711, telephone number:
(919) 541-2380; fax number: (919) 541-5509, or electronic mail at
svendsgaard.dave@epa.gov.
SUPPLEMENTARY INFORMATION:
I. General Information
A. What are the Regulated Entities?
Entities potentially affected by the subject rule for today's
action include sources in all industry groups. The majority of sources
potentially affected are expected to be in the following groups.
------------------------------------------------------------------------
Industry group SIC \a\ NAICS \b\
------------------------------------------------------------------------
Electric Services................... 491 221111, 221112, 221113,
221119, 221121,
221122.
Petroleum Refining.................. 291 324110.
Industrial Inorganic Chemicals...... 281 325181, 325120, 325131,
325182, 211112,
325998, 331311,
325188.
Industrial Organic Chemicals........ 286 325110, 325132, 325192,
325188, 325193,
325120, 325199.
Miscellaneous Chemical Products..... 289 325520, 325920, 325910,
325182, 325510.
Natural Gas Liquids................. 132 211112.
Natural Gas Transport............... 492 486210, 221210.
Pulp and Paper Mills................ 261 322110, 322121, 322122,
322130.
Paper Mills......................... 262 322121, 322122.
Automobile Manufacturing............ 371 336111, 336112, 336211,
336992, 336322,
336312, 336330,
336340, 336350,
336399, 336212,
336213.
[[Page 33839]]
Pharmaceuticals..................... 283 325411, 325412, 325413,
325414.
------------------------------------------------------------------------
\a\ Standard Industrial Classification.
\b\ North American Industry Classification System.
Entities potentially affected by the subject rule for today's
action also include State, local, and tribal governments.
B. How Is This Preamble Organized?
The information presented in this preamble is organized as follows:
I. General Information
A. What are the regulated entities?
B. How is this preamble organized?
II. Background
III. Today's Action
A. Three Issues for Which Reconsideration Was Granted
1. Legal Basis
2. The 20 Percent Replacement Cost Threshold
3. Revisions to the Format for Incorporating the PSD FIP into
State Plans
B. Remaining Issues in Petitions for Reconsideration
1. Petitioners' claim that EPA retroactively applied the ERP
2. Petitioners' claim that EPA cannot modify a State's SIP
without a finding of deficiency
IV. Statutory and Executive Order Reviews
A. Executive Order 12866--Regulatory Planning and Review
B. Paperwork Reduction Act
C. Regulatory Flexibility Act
D. Unfunded Mandates Reform Act
E. Executive Order 13132--Federalism
F. Executive Order 13175--Consultation and Coordination with
Indian Tribal Governments
G. Executive Order 13045--Protection of Children from
Environmental Health & Safety Risks
H. Executive Order 13211--Actions That Significantly Affect
Energy Supply, Distribution, or Use
I. National Technology Transfer and Advancement Act
J. Congressional Review Act
V. Statutory Authority
VI. Judicial Review
II. Background
On October 27, 2003, we published the Equipment Replacement
Provision (``ERP'') amendments to our regulations implementing the
major NSR requirements of the CAA.\1\ The ERP amended the exclusion
from major NSR for ``routine maintenance, repair, and replacement''
(``RMRR'') activities at existing major sources. Several parties sought
judicial review of the ERP in the U.S. Court of Appeals for the
District of Columbia Circuit. See State of New York v. EPA, No. 03-1380
and consolidated cases (DC Cir.). As a result of a court order, the ERP
is ``stayed'' (i.e., not in effect) until the court decides this case.
---------------------------------------------------------------------------
\1\ The October 27, 2003 final rule did not act on the ``Annual
Maintenance, Repair and Replacement Allowance'' approach that we
proposed on December 31, 2002 (67 FR 80920). We may act on this
portion of the 2002 proposal in a subsequent rulemaking.
---------------------------------------------------------------------------
On December 24, 2003, EPA published a rule amending the Prevention
of Significant Deterioration (PSD) provisions of state programs that
did not have approved state rules for PSD. 68 FR 74483. In each of
these states, EPA previously had made the area subject to the PSD rules
in 40 CFR 52.21, the Federal Implementation Plan (``FIP'') for PSD.
Please see 68 FR 74483 (December 24, 2003), for additional background
on this rule. Parties have also sought judicial review of this rule,
and their petitions for review have been consolidated with the
challenges to the ERP.
Also on December 24, 2003, a group of environmental organizations
\2\ petitioned EPA, pursuant to section 307(d)(7)(B) of the CAA, to
reconsider three aspects of the Equipment Replacement Provision that we
published on October 27, 2003. Specifically, the petitioners \3\
asserted that our legal basis for the ERP is flawed, the basis for the
20 percent ERP cost threshold is arbitrary and capricious, and EPA has
retroactively applied the ERP.
---------------------------------------------------------------------------
\2\ The following parties filed the petition for reconsideration
of the October 27, 2003 rule: Natural Resources Defense Council,
Environmental Defense, Sierra Club, American Lung Association,
Communities for a Better Environment, United States Public Interest
Research Group, Alabama Environmental Council, Clean Air Council,
Group Against Smog and Pollution, Michigan Environmental Council,
The Ohio Environmental Council, Scenic Hudson, and Southern Alliance
for Clean Energy.
\3\ In this notice, the term ``petitioner'' refers only to those
entities that filed petitions for reconsideration with EPA.
---------------------------------------------------------------------------
On January 16, 2004, a subset of the environmental petitioners on
the ERP rule filed a petition for reconsideration of the December 24,
2003 rule that incorporated the ERP into the FIP portion of a State
plan where the State does not have an approved PSD State Implementation
Plan (SIP). This petition reiterated the issues raised in the December
24, 2003 petition concerning the ERP. On February 23, 2004, a group of
states and the District of Columbia \4\ filed a petition for
reconsideration of the December 24, 2003 rule. This petition raised two
issues. First, it asked for reconsideration on whether EPA needed to
make a finding of deficiency for the PSD portions of each SIP before it
amended the incorporation of the PSD FIP into the state plans. Second,
it challenged whether EPA needed to provide an opportunity for comment
on the revised format for incorporating the PSD FIP into state plans,
which would automatically update the state plans whenever EPA amends
the PSD FIP.
---------------------------------------------------------------------------
\4\ The states that filed a petition for reconsideration of the
December 24, 2003 rule are California, Connecticut, Illinois,
Massachusetts, New Jersey, and New York, along with the District of
Columbia.
---------------------------------------------------------------------------
On July 1, 2004 (69 FR 40278), we granted reconsideration and
requested comment on three issues raised by petitioners--specifically,
the contentions that our legal basis is flawed, that our selection of
20 percent for the cost limit is arbitrary and capricious and lacks
sufficient record, and that we should provide an opportunity for
comment on the revised format for incorporating the PSD FIP into state
plans. We decided to grant reconsideration on these issues because of
the importance EPA attaches to ensuring that all have ample opportunity
to comment. At that time, we did not act on the remaining two issues in
those petitions.
On August 2, 2004, we held a public hearing on the issues for which
we granted reconsideration. Five individuals gave oral presentations at
the hearing. The transcript of their comments is located in Docket OAR-
2002-0068 (Legacy Number A-2002-04), which can be accessed on the
Internet at https://www.epa.gov/edocket.
The public comment period on the reconsideration issues ended on
August 30, 2004, and we allowed until September 1, 2004 to receive
public comments for issues arising out of the August 2nd public
hearing. More than 350 written public comments on the reconsideration
issues were received. The individual comment letters can be found in
Docket OAR-2002-0068 (Legacy Number A-2002-04).
III. Today's Action
At this time, we are announcing our final action on reconsideration
of the three issues for which we asked for comment in our July 1, 2004
notice. We
[[Page 33840]]
are also announcing our final decision on the remaining two issues that
were raised by the petitioners. We are making available a document
entitled, ``Technical Support Document for the Equipment Replacement
Provision of the Routine Maintenance, Repair and Replacement Exclusion:
Reconsideration,'' EPA 456/R-05-003. This document contains (1) a
summary of comments received on the issues for which we granted
reconsideration and our responses to these comments, and (2) a summary
of petition issues for which we are not granting reconsideration, and
our rationale for denying reconsideration. This document is available
on our Web site at https://www.epa.gov/nsr/; and, through the National
Technical Information Services, 5285 Port Royal Road, Springfield, VA
22161; telephone (800) 553-6846, e-mail https://www.ntis.gov; and, from
the U.S. EPA, Library Services, MD C267-01, Research Triangle Park, NC
27711, telephone (919) 541-2777, e-mail library.rtp@epa.gov.
A. Three Issues for Which Reconsideration Was Granted
1. Legal Basis
Our July 1, 2004 notice noted that underlying our legal rationale
for the ERP is a basic tenet of administrative law stated in Chevron,
U.S.A., Inc. v. NRDC, 467 U.S. 837 (1984). The Chevron Court held that
expert agencies have the discretion to reasonably interpret ambiguous
statutory terms and that such interpretations are due deference. Id. at
842-845. In the October 27, 2003 final rule and in the July 1, 2004
notice, we explained that the statutory definition of `modification,'
CAA 111(a)(4), and, in particular, the word ``change'' in the phrase
``any physical change or change in the method of operation,'' is
ambiguous. The word itself is ambiguous, and the use of ``any'' as a
modifier, in the context of the statute, simply requires EPA to include
an indeterminate number of changes as potential modifications \5\ once
EPA defines the ambiguous term ``change.'' The ERP, which establishes
criteria for determining what equipment replacement activities do not
constitute physical changes, is a rational interpretation of ``physical
change'' in the definition of ``modification.'' See 68 FR 61268-61274
for our more detailed legal support for the ERP.
---------------------------------------------------------------------------
\5\ A physical change would be a modification only if it
resulted in a significant emissions increase as we define the term.
---------------------------------------------------------------------------
In granting reconsideration, we invited comments on several legal
arguments suggested by commenters on the meaning of the statutory
definition of ``modification.'' In particular, we noted that commenters
had suggested that the plain meaning of the ``modification'' definition
required that functionally equivalent equipment replacements not be
deemed to be changes and, therefore, be deemed RMRR. We also noted that
other commenters took the opposite view about the plain meaning of the
statute. Both sides of this argument cited the principle from Chevron
that where the statute's meaning is clear, the agency must give its
meaning effect (the first step in statutory analysis under Chevron, or
Chevron 1). Some commenters had argued that only de minimis exceptions
could be allowed under the statute. Others had pointed out that a
recognized principle of administrative law allows an agency to
establish ``bright line'' criteria to reduce regulatory burden and
provide certainty. We invited comment on these arguments and any other
possible legal arguments when we granted reconsideration on the issue
of whether our legal basis in the ERP was flawed.
We received a number of comments supporting and opposing the legal
basis for our rule. Commenters renewed and expanded prior arguments
that the definition of ``modification'' was clear and either prohibited
or compelled treating like-kind replacements as physical changes when
replacement resulted in a potential emissions increase. Some comments,
summarized below, addressed Congressional intent as construed by
courts, provided specific textual analysis of the modification
definition, and offered policy objections to the ERP. We discuss
significant comments below and refer you to the TSD for this action for
additional discussion of comments and responses.
a. Congressional Intent. Commenters assert that the ERP is contrary
to Congressional intent and the decision in Alabama Power v. Costle,
636 F.2d 323 (D.C. Cir. 1979). They characterize the opinion as holding
that Congressional intent behind the modification provision was to
include any physical change that increases emissions, even though it
would undoubtedly prove inconvenient and costly to affected industries.
They cite a portion of the opinion that declared, ``the term
`modification' is nowhere limited to physical changes that exceed a
certain magnitude.'' Additionally, they claim the Court found EPA's
authority to exempt activity from ``modification'' was limited to de
minimis activity. Id. at 400.
We disagree with the commenters' reading of Alabama Power. Alabama
Power does not directly address whether like-kind replacements must be
deemed to be physical changes. The Alabama Power Court addressed an
exemption for physical changes that resulted in an emissions increase
of less than 100 tons. It is in this context, where the replacement
activity has been conceded to be a physical change, that the court
states that the modification definition ``is nowhere limited to
physical changes that exceed a certain magnitude.'' Alabama Power, 636
F.2d at 400. In context, the ``magnitude'' language only addresses the
size of the emission tonnage increase resulting from a ``change,'' once
the activity meets the definition of a ``change.'' The Court did not
have before it the question of whether the phrase ``any physical
change'' is ambiguous. Contrary to the commenter's assertions, the
cited portion of the Alabama Power opinion discusses a de minimis
exemption only in the context of emission increases and not in terms of
what constitutes a physical change (``EPA does have the discretion * *
* to exempt from PSD review some emission increases on grounds of de
minimis or administrative necessity''). Id.
Moreover, the Alabama Power Court also expresses the expectation
that ``bubbling'' (or netting) in calculating emission increases and an
allowance for physical changes that result in de minimis increases in
emissions ``will allow for improvement of plants, technological
changes, and replacement of depreciated capital stock, without imposing
a completely disabling administrative and regulatory burden.'' Alabama
Power, 636 F.2d at 400. (emphasis added). Our subsequent experience has
shown that, even with netting, a definition of ``physical change'' as
encompassing as that supported by these commenters is inadequate to
allow for appropriate replacement of depreciated capital stock. See
``New Source Review: Report to the President'', June 2002 (Docket No.
OAR-2002-0068, Document No. 0004). It simply is not the case that the
Alabama Power opinion analyzes and requires the commenters'
encompassing construction of ``any physical change.'' Equally
important, a narrow interpretation of ERP as advocated by commenters
would create hurdles for ensuring that a process operates reliably,
safely, and efficiently, thereby increasing the likelihood that net
emissions would be higher.
[[Page 33841]]
The commenters point to several enforcement filings and other EPA
pronouncements prior to promulgation of the ERP in which we said the
definition of modification was unambiguous and had broad application.
Furthermore, they note that we repeatedly recognized that the structure
of the Act demonstrates that Congress intended grandfathering to be of
limited duration.
We recognize that, prior to promulgation of the ERP, we had not
specifically asserted that our interpretation of ``change'' and the
exclusions from NSR are based on an exercise of Chevron discretion. In
some instances, such as in a decision of the Environmental Appeals
Board (EAB), In re: Tennessee Valley Authority, 9 E.A.D. 357 (EAB
2000), and in briefs in various enforcement-related cases, we had
interpreted ``change'' such that virtually all changes, even trivial
ones, were encompassed by the Act. Thus, we generally had interpreted
the exclusion as being limited to de minimis circumstances. However, in
the ERP we asserted that EPA does have the authority to interpret these
key terms through rulemaking. Upon further consideration of the history
of our actions, the statute, and its legislative history, we said that
we believe a different view is permissible, and, for policy reasons
discussed in the ERP final rule, more appropriate. Therefore, we
adopted our Chevron-based interpretation of the statute prospectively
in the ERP final rule.\6\
---------------------------------------------------------------------------
\6\ We noted in the ERP final rule: We have taken positions in
numerous court filings concerning the proper interpretation and
usage of key statutory terms, such as ``physical change'' and ``any
physical change.'' These positions were based on permissible
constructions of the statute of which the regulated community had
fair notice, and correctly reflect the Agency's reasonable
accommodation of the Clean Air Act's competing policies in light of
its experience at the time it adopted the RMRR exclusion in 1980.
The Agency has sought, and has obtained, deference for its
interpretations, and, notwithstanding today's adoption of a revised
interpretation of the statute and an expansion of the RMRR
exclusion, the Agency shall continue to seek deference for those
prior interpretations in ongoing enforcement litigation. 68 FR at
61272, fn 14.
---------------------------------------------------------------------------
Subsequent to promulgating the ERP, we filed court papers noting
that, as of the date of the final ERP rule, we adopted a new
interpretation of the statute. Our position is most clearly spelled out
in a filing we made in United States v. Illinois Power Co., et al.,
Civil Action No. 99-833 (S.D. Ill.) (``Illinois Power''). As we stated
to the Illinois Power Court, ``the United States does not rely on any
prior statements * * * that a very narrow construction of the ``routine
maintenance'' exemption is required by the Clean Air Act itself.
Instead, the United States will continue to rely on EPA's narrow
interpretation of its prior ``routine maintenance'' exception, which
remains applicable to this action.'' Illinois Power, Plaintiff's Reply
to Defendants' Proposed Findings of Fact and Conclusions of Law
(Liability Phase) at 5. We no longer interpret the language or
structure of the NSR provisions of the Act as an expression of
Congress's intent to limit ``grandfathering'' through the indirect
means of the ``modification'' provision rather than through other
provisions that clearly can reach all existing sources. See, e.g., CAA
section 110 (SIP provisions); CAA section 112 (hazardous air pollutant
provisions); CAA sections 401-416 (acid rain provisions).
Finally, one group of commenters argues that Congress's decision in
1977 to cross-reference the preexisting definition of ``modification''
in CAA section 111(a)(4) when it adopted the modification provision for
NSR should have no impact on assessing whether the terms of the
definition are ambiguous. They cite EPA's arguments in our August 2004
brief in State of New York v. EPA, D.C. Cir. Case No. 02-1387, which
refuted arguments that EPA is compelled to interpret both the NSPS and
the NSR modification provisions the same way. They construe the ``legal
basis'' discussion in our October 27, 2003, ERP final rule as arguing
that Congress ratified our ERP interpretation when it enacted the 1977
amendments.
We disagree with the characterization of our argument in the
October 27, 2003 preamble to the final ERP rule. Nowhere in that notice
do we argue that Congress mandated adoption of the 1977 NSPS regulatory
interpretation of what is a ``modification'' when it cross-referenced
the definition in CAA 111(a)(4) into the NSR program. As we discussed
in the cited passages of our briefs, we do not believe Congress
intended to ratify the then-existing interpretation or ``congeal'' our
NSR regulations as they stood under the NSPS program in 1977. Our
discussion of the history of our interpretation of CAA 111(a)(4) simply
points out the obvious: that words of CAA 111(a)(4) historically have
been taken to have quite different meanings in the NSR and NSPS
programs. From this, we argue that any words that can be given such
divergent meanings for decades cannot have but one clear meaning on
their face. To argue that the definition of ``modification'' in CAA
111(a)(4) is unambiguous, as the commenters have, one must advance an
unusual position: that the same words, with no further definitions or
legislative history, facially and unambiguously mean different things.
b. Textual analysis of the modification definition. It is axiomatic
that the most clear expression of what Congress intended by the
``modification'' definition is in the words it chose to use. Many
significant comments we received analyzed the structure of the
definition and particular words and phrases in it.
One commenter argued that the statutory term ``modification''
itself is not ambiguous, so the definition of modification should not
be read to create ambiguity in the term. The commenter, who argued that
the ERP is too generous in excluding equipment replacements from NSR,
observed that the plain meaning of modification connotes moderate, as
opposed to fundamental, change.
We disagree with the assertion that the ERP allows for
``fundamental'' change in an emission source. In focusing on the 20
percent criterion of the ERP, the commenter ignores other important
criteria under the ERP that would, in any ordinary sense of the term,
prohibit the possibility of fundamental change as a result of
activities that meet the ERP exclusion. A source that maintains its
basic design parameters is not fundamentally changed, nor is a source
that replaces one piece of equipment with another that is functionally
equivalent. Thus, the ERP does not allow for fundamental change of the
type the commenter suggests that the term ``modification'' should
prohibit. In fact, to clarify this, the ERP explicitly precludes
activities that would change the basic design parameters from
qualifying for a RMRR exclusion.
Moreover, we disagree with the commenter's assertion that the term
``modification'' itself is unambiguous and in no need of further
clarification. In fact, we note that over the years permitting
authorities have had to respond to numerous queries regarding whether
certain activities constitute a ``modification,'' a testament that
there is considerable ambiguity surrounding this term. Apparently,
Congress agrees with our view, because it supplied further definition
in CAA 111(a)(4).
Many of the comments focused on the significance of the modifier
``any'' in ``any physical change or change in the method of
operation.'' In our October 27, 2003 final rule, we said that the word
``any'' did not compel EPA to define what constitutes a ``physical
change'' to include all activities that could conceivably be defined as
a physical change. In our view, we had discretion to define what
activities were
[[Page 33842]]
physical changes, and once we defined physical change, ``any'' simply
meant that any activity that met our definition of physical change
could be a modification if it also increased net emissions.
In our July 1, 2004 notice, we invited comment on a recent Supreme
Court case that construed a prohibition on states and localities
enacting legislation to bar ``any entity'' from offering interstate
telecommunications services to not apply to legislation that restrained
political subdivisions of states from entering the field. Nixon v.
Missouri Municipal League, 541 U.S. 125, 124 S. Ct. 1555, 1559-60
(2004). The Nixon Court observed that Congress's understanding of
``any'' can differ depending upon the statutory setting. Id. at 1561.
This opinion reversed a case litigants had relied upon in seeking a
stay of the ERP on the proposition for which it was cited.\7\
---------------------------------------------------------------------------
\7\ State and Municipal Petitioners' Emergency Motion for a
Stay, State of New York v. EPA, D.C. Cir. No. 03-1380 and
consolidated cases, at 8 fn.14 (citing Missouri Mun. League v. FCC,
299 F.3d 949, 954 (8th Cir. 2002), rev'd sub nom. Nixon v. Missouri
Mun. League, 541 U.S. 125, 124 S. Ct. 1555 (2004)). A copy of this
motion was submitted to the record as a comment on the
reconsideration notice.
---------------------------------------------------------------------------
In discussing the significance of the modifier ``any'' in the
statute and in discussing the Nixon case, commenters opposed to the ERP
argued that numerous cases besides Nixon have held that terms modified
by the word ``any'' must be given the most inclusive meaning possible,
that such terms must be interpreted expansively, and that ``any'' has a
broad meaning.\8\ These commenters distinguished Nixon on the grounds
that this case raised peculiar federalism concerns (i.e., the ability
of a state to regulate its own political subdivisions) not present in
CAA 111(a)(4) or the ERP.
---------------------------------------------------------------------------
\8\ E.g., Harrison v. PPG Industries, 446 U.S. 578 (1980);
United States v. Gonzales, 520 U.S. 1 (1997); Department of HUD v.
Rucker, 535 U.S. 125 (2002). A post-Nixon addition to this line of
cases is Norfolk Southern Railway Co. v. James N. Kirby, Pty Ltd.,
125 S. Ct. 385 (2004).
---------------------------------------------------------------------------
Several other precedents establish that the principle on which
Nixon relies, that the understanding of ``any'' can depend on the
statutory context, is not limited to situations with federalism
implications. E.g., O'Connor v. U.S., 479 U.S. 27, 31 (1986) (statutory
context shows ``any taxes'' limited to taxes of the Republic of
Panama); Mastro Plastics Corp. v. NLRB, 350 U.S. 270-85 (1956) (``any
strike'' does not include strike in response to unfair labor
practices); Bell Atlantic Tel. Cos. v. FCC, 131 F.3d 1044, 1047 (D.C.
Cir. 1997) (FCC regulation narrowing ``any * * * facilities or
services'' that a Bell operating company could offer affirmed when
Court notes ``textual analysis is a language game played on a field
known as `context'''). Therefore, we believe the ``broader frame of
reference'' adopted by the Nixon Court is not an isolated and
unsupported view of the law limited to cases raising federalism
concerns.
None of the cases cited by the commenters stand for the proposition
that a term modified by the word ``any'' invariably must be given its
broadest meaning. In Harrison and in other cases, the Court found ``no
indication whatever'' that Congress intended a narrower or limited
construction of statutory term. These cases discuss a different
statutory context than the adoption of the definition of
``modification'' in the NSR provisions of the CAA. These cases do not
involve a situation in which Congress incorporated into a section of a
statute a term that had been used in another section of the statute and
which had been given a different meaning under that prior section.
While there is no evidence that Congress compelled EPA to replicate its
NSPS interpretation of ``any physical change'' in the NSR program, the
fact that the words at issue were given a different construction in the
NSPS is an indication that the words do not have a unique and,
therefore, unambiguous meaning.
The cases cited by the petitioners and the Nixon line of cases are
not, in fact, opposing and contradictory. Both support looking for
indications in the statute that suggest a more limited meaning of the
modified term is possible or intended. We believe such indications
exist in the NSR context because the modification definition inserted
into the NSR provisions by a 1977 technical amendment to the 1977 CAA
Amendments cross-referenced the pre-existing term under CAA 111(a)(4).
Implicitly, at least one of the commenters critical of the ERP
recognized that a broader frame of reference can apply by arguing that
while in Nixon, a broad construction of ``any'' would have led to
absurd, futile, and farfetched results, the same would not be true for
the NSR modification definition. For NSR, according to the commenters,
Congress placed a clear limit on what changes must be considered
modifications--those that increase emissions.
In the definition of ``modification,'' we believe a view that
``any'' compels a broad construction of the modified terms also has
farfetched implications. The same word ``any'' that modifies ``physical
change in'' also modifies ``change in the method of operation of.'' The
commenters' argument proves too much. The argument would say that
exemptions from the definition of modification on any basis other than
de minimis increases would not be necessary or appropriate, even long
accepted ones that limit the scope of ``change in the method of
operation.'' As the preamble to the final rule notes, many of these
exemptions can result in non-de minimis increases in emissions. 68 FR
at 61272. To accept the commenter's argument would mean that one word
(``change'') that modifies two clauses in a definition compels a broad
construction of one modified clause while allowing discretion when it
modifies the other clause.
Another commenter picks up on Nixon's reliance on the doctrine of
avoiding absurd or futile results and echoes the view that this
doctrine would not apply in the context of the modification definition.
In this commenter's view, EPA cannot claim that a broad construction of
``any physical change'' would lead to absurd or futile results when we
adopted such a broad construction of ``any physical change'' in the
past and continue to seek deference for such an interpretation in
ongoing enforcement litigation.
We do not claim our prior interpretation is absurd or futile. The
Agency claims that the use of the word ``any'' in the statute does not
compel only our prior interpretation.
We note that under the NSPS program, we interpreted CAA 111(a)(4)
to allow us to exempt ``[m]aintenance, repair, and replacement which
the Administrator determines to be routine for a source category.'' 40
CFR 60.14(e)(1). In contrast, under the NSR program, historically we
have interpreted the RMRR provision on a case-by-case basis, and we
have not followed suit with the NSPS program in determining that the
same activities are categorically exempt from RMRR. Thus, a
modification that is categorically exempt under the NSPS could be
potentially subject to NSR under our historical RMRR interpretation. It
would be incongruous to argue that the identical statutory text
incorporated into both the NSPS and the NSR provisions ``clearly''
could support only one meaning in the NSR context while it supports a
different meaning in the NSPS context. Rather than saying CAA 111(a)(4)
is clear but has two distinct meanings, common sense suggests the
wording is ambiguous and allows for an expert agency to adopt
reasonable interpretations in the context of the programs.
Commenters incorrectly claim that we have recognized all equipment
replacements, including ``like-kind''
[[Page 33843]]
replacements, to be ``physical changes'' within the ordinary meaning of
the word. While our October 27, 2003, final rule recognized that
``change'' is susceptible to multiple meanings, and outlined many
common uses of the word, we did so to illustrate that there is no one,
unambiguous, common meaning for the word. That is the essence of
ambiguity.
Several commenters agreed with our view that ``any'' should be
interpreted within the ``broader frame of reference'' of its statutory
context. One commenter argued that Nixon undermined much of the logic
in Wisconsin Electric Power Co. v. Reilly, 893 F.2d 901 (7th Cir. 1990)
(WEPCO). That case contains sweeping language that repeatedly stressed
that ``any'' compelled a broad interpretation of ``any physical
change.''
As we noted in our October 27, 2003 final rule, we believe that the
WEPCO Court was correct to determine that the statute does not
unambiguously allow all like-kind replacements to avoid NSR, which was
the position advanced by WEPCO in that litigation and which is the
position advanced in this reconsideration by certain commenters. The
Court's conclusion that the statute does not compel the outcome favored
by WEPCO leads to a result that is completely consistent with our
current view. Additionally, we continue to believe that the activities
at issue in WEPCO were not RMRR under the rules at issue in that case.
Furthermore, we continue to believe that, under the ERP, the equipment
replacements at issue in that case would not automatically qualify as
being excluded from major NSR. However, we agree with the commenter
that Nixon calls into question the additional discussion in WEPCO that
construes ``any'' to compel a broad view of what is a ``physical
change.'' In our view, ``any physical change'' is an ambiguous term
that can be defined by the Agency through rulemaking.
Focusing on a different portion of the definition of
``modification,'' commenters argue that Congress provided the only
acceptable limitation on what physical changes are not subject to NSR
as a modification, which is the requirement that the physical change
result in an increase in emissions of any pollutant or the emission of
any pollutant not previously emitted.\9\ Commenters argue that an
agency cannot imply an exemption to, or otherwise insert limiting
language into, a categorical statutory provision, especially where
Congress was specific in how it would allow the language to be limited.
---------------------------------------------------------------------------
\9\ We note that it is to these limitations the Alabama Power
Court said that we could establish de minimis increase levels.
---------------------------------------------------------------------------
We disagree with the commenters on three grounds. First, the
commenters seem to assume the answer to the threshold question--that
equipment replacements that meet the ERP criteria are ``physical
changes''--in order to say that we are creating an exemption for
activity that is presumptively subject to NSR. We believe that there is
no such presumption prior to the agency defining the ambiguous term.
Second, we believe that the implication of the commenters' argument
would mean that several long-accepted exemptions from NSR would no
longer be valid were their position adopted. These exemptions from
``any * * * change in the method of operations'' were discussed in our
final rule legal basis. Finally, we believe that the commenters'
argument would not give meaning to all the words of the definition of
modification. The commenters' position reads the ``any physical change
or change in the method of operation'' to be so inclusive that
essentially the test for a modification becomes whether emissions
increase at a source because there always will be some ``change'' to
which the increase can be linked. In contrast, the ERP, as part of our
overall approach to the definition of modification, gives meaning to
both the ``change'' portion as well as the ``emissions increase''
portion of the definition.
To summarize: With respect to existing sources, the purpose of the
NSR provisions is simply to require the installation of controls at the
appropriate and opportune time. The kind of replacements that
automatically fall within the equipment replacement provision
established today do not represent such an appropriate and opportune
time. Accordingly, and given that it is consistent with the meaning of
``change'' to treat this kind of replacement as not being a ``change,''
we believe excluding them on that basis from the definition of
``modification'' as used in the NSR program is well calculated to serve
all of the policies of the NSR provisions of the CAA, and is therefore
a legitimate exercise of our discretion under Chevron, U.S.A. Inc. v.
NRDC, 467 U.S. 837 (1984), to construe an ambiguous term. Likewise, we
believe this approach is consistent with the holding in the WEPCO case,
and with some though not all of that case's reasoning.
Finally, one comment argued that EPA's position on the meaning of
``change'' is internally inconsistent. If equipment replacement is not
a change, then the comment suggests EPA lacks authority to regulate
changes that exceed 20 percent of the replacement cost. If equipment
replacement is a change, then the comment suggests that an exemption
can only be justified by de minimis authority.
We note that establishing bright line criteria in a manner that
reduces regulatory cost and provide certainty is a well-recognized and
accepted approach to clarifying ambiguous terms in statutes. See Time
Warner Entertainment Co. LP v. FCC, 240 F.3d 1126, 1141 (D.C. Cir.
2001). The ERP simply establishes bright lines for when an equipment
replacement activity is automatically excluded from major NSR.
As we explained in our final ERP rule preamble, this approach is
consistent with our approach towards ``reconstruction'' in the NSPS
context. Under the NSPS rules, we treat a 50 percent threshold as a
trigger for scrutiny as to whether the source must meet the NSPS. 40
CFR 60.15(b)(1). We then assess the technological and economic
feasibility of meeting the NSPS standard. 40 CFR 60.15(b)(2).
In the ERP, we do not take the position that all like-kind or
functionally-equivalent replacements automatically are or are not
changes. Instead, we simply draw criteria for when such activities are
excluded from NSR and when the multi-factor RMRR approach applies.
c. Policy objections. Several comments disputed the manner in which
we exercised our discretion in defining which equipment replacement
activities are not changes. As noted below, these comments tended to
infer that we were defeating Congressional intent through the practical
effects of the ERP.
Some commenters criticize the ERP as allowing for perpetual
immunity from emissions control requirements. These commenters claim
that the ERP reflects EPA's disagreement with Congress's determination
that the time to install controls is when a unit is modified. In the
commenters' opinion, EPA's belief that it is not plausible that
replacements would proceed if emissions controls needed to be installed
lacks a factual basis and is contrary to the statutory scheme.
Our disagreement over what constitutes a modification is with the
commenter and not Congress. Major source NSR permitting is required
unless the source can meet the criteria of the ERP, is not otherwise
exempt under the RMRR provision or another NSR exemption or exclusion,
and the source does not accept enforceable
[[Page 33844]]
emissions limit below the significant emissions increase levels. When a
replacement is a modification under our clearer, more focused
definition, NSR permitting will apply, consistent with the Act.
We do not believe, however, the modification provisions of the CAA
should be interpreted to ensure that all major facilities either must
eventually trigger NSR or must degrade in performance, safety, and
reliability. In fact, such an interpretation cannot be squared with the
plain language of the CAA. An existing source triggers NSR only if it
makes a physical or operational change that results in an emissions
increase. Thus, a facility can conceivably continue to operate
indefinitely without triggering NSR--making as many physical or
operational changes as it desires--as long as the changes do not result
in emissions increases. This outcome is an unavoidable consequence of
the plain statutory language and is at odds with the notion that
Congress intended that every major source would eventually trigger NSR
or otherwise fall into disrepair. Moreover, there is nothing in the
legislative history of the 1977 Amendments, which created the NSR
program, to suggest that Congress intended to force all then-existing
sources to go through NSR. To the extent that some members of Congress
expressed that view during the debate over the 1990 amendments, such
statements are not probative of what Congress meant in 1977. Central
Bank of Denver, N.A. v. First Interstate Bank of Denver, N.A., 511 U.S.
164, 185--86 (1994), and cases cited.
To the extent that our preamble to the ERP final rule suggested
that no replacements ever would take place if controls were required,
we recognize that such a generalization is not established by the
record, nor was it our intent to make such a sweeping statement.
Nevertheless, the substantial body of testimony and studies in the
record demonstrates that the vagueness of the RMRR provision operated
as a substantial restraint on replacement activity even when such
activity would result in safer, more efficient, more reliable processes
that had the potential to lower emissions in the overall economy by
displacing higher polluting production. See ``New Source Review: Report
to the President'', June 2002 (Docket No. OAR-2002-0068, Document No.
0004). Based on the record, we believe that an owner or operator of a
source often has the financial incentive to repair existing equipment
or artificially constrain production, rather than install emission
controls. Therefore, as a general matter, the replacement of that
equipment is not, in fact, an opportune time for the installation of
such controls. It follows that a policy treating such replacements as
an NSR trigger generally will not lead to the installation of controls.
Rather, it will merely create incentives to make a plant less
productive than its design capacity would allow it to be.
These commenters also claim that Congress intended to strike a
different balance between the nation's economic and environmental
interests than that which the ERP strikes. They believe requiring
emission controls on modified sources would facilitate economic growth
and preserve air quality. They point out that the 1977 House Committee
report noted, when the emissions impact of each new or modified plant
is minimized, ``then more and bigger plants will be able to locate in
the same area without serious air quality degradation.''
We agree that we strike the balance between productive capacity of
the nation and the protection of the environment differently than these
commenters would. We disagree with the assertion that the balance we
struck inappropriately weights either consideration. To the extent that
Congress left discretion to anyone in striking such a balance, it is
afforded to the Administrator and not to litigants. The record
demonstrates that our approach, in concert with other CAA programs, is
consistent with preserving clean air resources and improving air
quality in areas that are not attaining the NAAQS as well as Congress's
intentions written explicitly in Sec. 101(b)(1) to preserve the
productive capacity of the nation's population and in Sec. 160(3) to
balance economic and environmental concerns.
When balancing the economic and environmental interests of the
nation, we have also considered that there are many other systematic
air programs that will not merely prevent emission increases from
existing sources but even reduce emissions at sources we expect to use
the ERP. In fact, the entire state implementation plan (SIP) program
under Sec. 110(a) establishes a framework for systematic reduction of
emissions from existing sources when such reductions are deemed
necessary to meet or maintain the NAAQS. The CAA places primary
responsibility on the States to achieve the emissions reductions needed
to attain and maintain the NAAQS. Over the years, States have in fact
achieved significant emissions reductions in furtherance of this
obligation.
To assist States, we have developed model market-based programs
patterned after the successful Acid Rain provision in Title IV of the
CAA. For example, EPA's recently issued ``Clean Air Interstate Rule
(CAIR),'' will ensure, through States adopting a ``cap and trade'' or
other program approach, that overall emissions from electric utilities
throughout much of the Eastern part of the country will meet overall
emission limits that are sharply below that which they emit today. CAIR
ensures that, by 2015, SO2 and NOX emissions will
be permanently reduced by 5.4 million tons and 2.0 million tons,
respectively, over 2003 levels. Additional emission reductions will
occur after 2015 when CAIR is fully implemented.
There are other CAA programs, as well, that are specifically
tailored to require emission reductions from existing utility and
nonutility sources. These programs include the Maximum Achievable
Control Technology (MACT) standards that apply to new and existing
sources of air toxics and Control Technique Guidelines that provide
guidance to states in determining Reasonably Available Control
Technology (RACT) for sources in ozone nonattainment areas. All of
these CAA measures will apply systematically to existing sources, and
are unaffected by the applicability or non-applicability of any NSR
exclusion, such as the RMRR exclusion and its further definition as set
forth in the ERP. And, in appropriate circumstances, a State may seek
to use CAA Section 126 to petition for additional controls on out-of-
state sources.
Even in the absence of these other CAA programs, we note that the
substitution effect of replacing deteriorating emission sources with
well-maintained emission sources will generally reduce emissions per
unit of output. The ERP itself should not materially affect demand in
markets. Thus, to the extent individual sources will increase output
(and emissions) following maintenance allowed by the ERP, output (and
emissions) at other plants will decrease. Thus, we conclude that the
ERP will not lead to an overall emission increase.
In contrast to the CAA programs discussed above that systematically
and efficiently obtain emission reductions, the NSR program for
existing sources, as that program existed before the ERP, was applied
in a scattershot manner, only triggered by ``modifications'' however
defined on a case-by-case manner. Under NSR, emissions reductions can
only be obtained in a ``catch-as-catch-can'' manner, and there never
has been and never can be a date
[[Page 33845]]
certain by which all existing sources in an area of the country must
comply with an emission cap or a NAAQS. Moreover, as fully explained in
our recent brief filed in defense of the NSR Improvements Rule of
December 31, 2002, the NSR program is not an emission reduction
program. It is a program to limit emission increases resulting from
physical and operational changes. Brief for Respondent at 73-75, State
of New York v. U.S. EPA, No. 02-1387 & consolidated cases (D.C. Cir.)
(``If Congress had intended to compel decreases in emissions, it would
be irrational for the requirement to be triggered only when a facility,
in fact, increases its emissions''). In light of the programs under the
Act that systematically and efficiently allow for both reductions in
emissions and firm caps on emissions, and the scattershot applicability
and limited goals of NSR program with respect to existing sources, it
was appropriate for us to strike the balance of economic and
environmental interests in accordance with the CAA, as we did when we
changed our method for implementing the modification definition in the
NSR program.
Commenters suggest that EPA's decision in promulgating the ERP is
not entitled to deference because, in their view, it appears that
Congress would not have sanctioned an interpretation that allows
sources to conduct multi-million dollar refurbishment activities that
increase emissions without triggering NSR. However, the record
establishes that adoption of the ERP will not cause overall emissions
to increase, while, at the same time, safety, efficiency, and
reliability of plants will improve. Furthermore, improvements in
safety, efficiency, and reliability improve environmental performance
by minimizing the frequency of startup, shutdowns, and malfunctions.
While the record contains some conflicting data and studies, Congress
left the weighing of this information and the forming of policies based
on this information to EPA as an expert agency. We considered the
quality and validity of the submitted data and studies in developing
our conclusions. Our decisions in this matter are entitled to deference
under Chevron.
2. The 20 Percent Replacement Cost Threshold
In the December 31, 2002 proposed rule, EPA solicited comments on
the ERP approach. At that time, we sought input on a range of possible
percentages of cost that could serve as one of the criteria that must
be met to qualify for the RMRR exclusion from NSR. We asked for comment
on percentages ranging up to 50 percent, the threshold for
reconstruction under the New Source Performance Standards (NSPS)
program. 67 FR at 80301.
Under the ERP, a project must meet four separate requirements
before it is automatically excluded from NSR pursuant to the ERP. The
20 percent replacement cost threshold is but one of the four
requirements. Thus, projects that meet the 20 percent threshold are not
exempt from major NSR under the ERP if they do not meet the other
necessary criteria in the final rule. These other criteria require that
the replaced component: (1) Be identical or functionally equivalent;
(2) does not alter the basic design parameters of the process unit; and
(3) does not cause the process unit to exceed any emission limitation
or operational limitation (that has the effect of constraining
emissions) that applies to any component of the process unit and that
is legally enforceable.
Some commenters have asserted that an equipment replacement project
would be excluded from NSR if it costs 20 percent or less of the
replacement cost of a process unit. However, a replacement project must
meet all four of the ERP criteria for the ERP to apply. Thus, only if
the replaced component is (1) identical or functionally equivalent, (2)
does not alter the basic design parameters of the process unit, and (3)
does not cause the unit to exceed any emission or operational limit,
will the 20 percent criterion be relevant. Of all of these qualifiers,
including the 20 percent cost threshold, the key qualifier is that the
equipment replacement is ``like-kind'' (i.e., identical or functionally
equivalent). This criterion provides strong support for our
determination and conclusion that where the ERP applies, the process
unit has undergone ``no change'' as a result of the activity at issue.
Thus, the 20 percent cost threshold serves primarily as an
administrative threshold, by which activities that fall beneath
threshold and which also meet the other rule criteria safeguards
qualify automatically as RMRR, while those activities that meet the
other criteria but are over the 20 percent cost threshold may still be
RMRR, but only by applying the multi-factor RMRR approach.
In the final ERP, we presented policy arguments and data analyses
supporting 20 percent of replacement costs of a process unit as the
threshold cost that would entitle an equipment replacement activity (or
aggregation of activities) to qualify automatically as RMRR, if the
other three criteria were met. See 68 FR 61255-61258. In short, we
received a substantial amount of industry data--both from electric
utilities and from other industry sectors--that supported a decision to
set the threshold at 20 percent. These data show that many like-kind
replacements occurring at facilities typically cost less than 20
percent of the process unit's value and do not increase emissions. We
also conducted case studies on a number of industries, analyzed the
costs involved in the Wisconsin Electric Power Company v. Reilly
(``WEPCO'') case (See 893 F.2d 901 (7th Cir. 1990)) and other relevant
information, and provided a legal basis as to why 20 percent is a
reasonable ERP cost threshold for equipment replacements across all
industries. We also stipulated other rule criteria which must be met to
qualify for the ERP. The ERP allows sources to know, with certainty,
that RMRR can be conducted without delay in situations where the 20
percent replacement cost criterion and other specified criteria are
met.
Petitioners asked EPA to reconsider the 20 percent cost threshold,
and claimed that none of EPA's arguments supporting the threshold had
appeared in the proposed rule. We granted reconsideration on this issue
and solicited additional comment on the data, our analyses, and the
policy considerations supporting the 20 percent threshold. We also
invited comment on whether it is appropriate to consider approaches
used by local governments in determining construction building code
applicability when establishing criteria for RMRR determinations.
Thus, our goal in selecting the cost threshold is not to create a
bright line below which any activity is excluded solely based on its
cost. Rather, the threshold is intended to operate in combination with
the three other ERP criteria as a screen for determining when the
multi-factor RMRR approach is applicable and when it is appropriate to
automatically exclude an activity as RMRR based on satisfying the three
non-cost ERP criteria. As discussed below, we continue to believe that
20 percent is an appropriate threshold for this purpose. The available
data indicate that the 20 percent threshold will effectively identify
those more significant projects for which applying the multi-factor
RMRR approach is prudent.
Another important factor of the ERP is that related activities must
be aggregated in the same way as they would have to be aggregated for
other NSR applicability purposes. Under our current policy of
aggregation, two or more replacement activities that occur
[[Page 33846]]
at different times are not automatically considered separate activities
solely because they happen at different times. In the case of replacing
an entire facility, it is not feasible that an owner or operator could
successfully argue that multiple projects occurring one after the other
are not related to one another and should not be aggregated for
applicability purposes. These other rule criteria play an important
part in determining what replacements can qualify for the ERP.
Much of the comment on the 20 percent replacement value threshold
focused on our use of six non-utility case studies that we believe
support our selection of a 20 percent replacement value threshold.
Though equipment replacement activities vary widely across industry
sectors, the six industry sector studies (pulp and paper mills,
automobile manufacturing, natural gas transmission, carbon black
manufacturing, pharmaceutical manufacturing, and petroleum refining)
indicated that equipment replacement activities of the type allowed
under the ERP generally do not cause increases in actual emissions.
Additionally, though the six studies address specific case examples
from only a part of regulated industry, the data indicated that most
typical replacement activities fall within the 20 percent threshold,
and that some major replacement activities will cross the 20 percent
threshold and be subject to the multi-factor RMRR approach.
We received a number of comments through the reconsideration
process that were supportive of the calculations performed in the case
studies of the six industries. Many of these comments came from the
trade groups representing industries that were analyzed in the case
studies. These organizations--including the American Forest & Paper
Association, Alliance of Automobile Manufacturers, National
Petrochemical & Refiners Association, and Interstate Natural Gas
Association of America--supported the analyses conducted and
conclusions reached in the case studies for each of their industries.
In some cases, these trade groups provided further amplification of
their cost ranges for projects, which provided additional depth and
support to the conclusions of the report. Other commenters stated that
the case studies failed to provide sufficient data to support the 20
percent cost threshold.
We never claimed that the case studies encompassed all equipment
replacement activities at these industries. Further, we recognize that
the case studies do not justify exempting all ``routine'' equipment
replacement activity in any one of the case study industries. As
discussed elsewhere in this notice, activities falling below the 20
percent replacement value threshold are not exempt under the ERP if
they do not meet the other three criteria of the rule. It is important
to note that the case studies were performed prior to decisions on the
exact form and content of the final rule. If the studies had chosen a
different set of assumptions (e.g., for costing of projects, or in
defining the process unit), they may have identified additional
equipment replacement projects exceeding 20 percent in cost.
Furthermore, these studies showed industry-wide results, not plant-
specific determinations. Under the ERP, if a plant-specific replacement
activity does not satisfy all four of the criteria that must be met to
qualify for the RMRR exclusion, then the activity is subject to the
multi-factor RMRR approach. The studies indicate that larger, less
frequent maintenance activities could exceed the ERP cost threshold
and, consequently, would be subject to the multi-factor RMRR
approach.\10\ Thus, we do not believe there is a basis, nor did the
petitioners provide one, that all equipment replacements in these
industries would be exempt under a 20 percent cost threshold.
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\10\ As the Alliance of Automobile Manufacturers appointed out
in their comment letter, despite the claims of the petitioners, the
Abt Study did consider typical replacement project for their
industry that exceeded the 20 percent cost threshold.
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We continue to believe that this information on other industrial
sectors beyond electric utilities supports our 20 percent bright line
test. In short, the case studies support our view that it is reasonable
to assume that equipment replacement activities in the utility industry
are similar enough to replacement practices in other industry, such
that the 20 percent value determined for utilities is appropriate for
industry as a whole.
While most industry commenters agreed that the 20 percent threshold
was adequate and reasonable and was well supported by available data,
several industry commenters provided additional data as further support
that the 20 percent threshold is appropriate. For example, Solar
Turbines estimates for