National Emission Standards for Hazardous Air Pollutants for Source Categories: Gasoline Distribution Bulk Terminals, Bulk Plants, and Pipeline Facilities; and Gasoline Dispensing Facilities, 1916-1953 [E7-25400]
Download as PDF
1916
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
ENVIRONMENTAL PROTECTION
AGENCY
40 CFR Part 63
[EPA–HQ–OAR–2006–0406, FRL–8512–3]
RIN 2060–AM74
National Emission Standards for
Hazardous Air Pollutants for Source
Categories: Gasoline Distribution Bulk
Terminals, Bulk Plants, and Pipeline
Facilities; and Gasoline Dispensing
Facilities
Environmental Protection
Agency (EPA).
ACTION: Final rule.
AGENCY:
SUMMARY: This action promulgates
national emission standards for
hazardous air pollutants for the facilities
in the gasoline distribution (Stage I) area
source category. We are promulgating
these emission standards for hazardous
air pollutants pursuant to Clean Air Act
section 112(c)(3) and 112(d)(5). We are
adding two regulations that address the
facilities contained in this area source
category. The first includes
requirements for bulk distribution
facilities, i.e., gasoline distribution bulk
terminals, bulk plants, and pipeline
facilities. The second includes
requirements for loading of storage
tanks at gasoline dispensing facilities.
We are also incorporating by reference
four test methods. This action also
finalizes our decision not to regulate the
above noted facilities under Clean Air
Act section 112(c)(6).
DATES: These final rules are effective on
January 10, 2008. The incorporation by
reference of certain publications listed
in the rule is approved by the Director
of the Federal Register as of January 10,
2008.
ADDRESSES: EPA has established a
docket for this action under Docket ID
No. EPA–HQ–OAR–2006–0406. All
documents in the docket are listed on
the www.regulations.gov Web site.
Although listed in the index, some
information is not publicly available,
e.g., confidential business information
or other information whose disclosure is
restricted by statute. Certain other
material, such as copyrighted material,
is not placed on the Internet and will be
publicly available only in hard copy
form. Publicly available docket
materials are available either
electronically through
www.regulations.gov or in hard copy at
the Air and Radiation Docket in the EPA
Headquarters Library, EPA West
Building, Room 3334, 1301 Constitution
Ave., NW., Washington, DC. 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. The Air and Radiation
Docket and Information Center’s Web
site is: https://www.epa.gov/oar/
docket.html. The electronic mail (email) address for the Air and Radiation
Docket is: a-and-r-Docket@epa.gov, the
telephone number is (202) 566–1742,
and the Fax number is (202) 566–9744.
FOR FURTHER INFORMATION CONTACT:
General and Technical Information: Mr.
Stephen Shedd, Office of Air Quality
Planning and Standards, Sector Policies
and Programs Division, Coatings and
Chemicals Group (E143–01), EPA,
Research Triangle Park, NC 27711,
telephone: (919) 541–5397, facsimile
number: (919) 685–3195, e-mail
address: shedd.steve@epa.gov.
Economic Analysis Information: Mr.
Tom Walton, Office of Air Quality
Planning and Standards, Health and
Environmental Impacts Division, Air
Benefit and Cost Group (C339–01), EPA,
Research Triangle Park, NC 27711,
telephone: (919) 541–5311, facsimile
number: (919) 541–0242, e-mail
address: walton.tom@epa.gov.
Compliance Information: Ms. Maria
Malave, Office of Compliance, Air
Compliance Branch (2223A), EPA, Ariel
Rios Building, 1200 Pennsylvania
Avenue, NW., Washington, DC 20460,
telephone: (202) 564–7027, facsimile
number: (202) 564–0050, e-mail
address: malave.maria@epa.gov.
SUPPLEMENTARY INFORMATION:
Outline. The information presented in
this preamble is organized as follows:
I. General Information
A. Does this action apply to me?
B. Where can I get a copy of this
document?
C. Judicial Review
NAICS a
Category
yshivers on PROD1PC62 with RULES2
Industry .....................................................
324110
493190
486910
424710
447110
447190
II. Background Information
III. Summary of Final Rules and Changes
Since Proposal
A. Applicability and Compliance Dates
B. Summary of Emission Limits and
Management Practices
C. What are the testing and initial
compliance requirements?
D. What are the notification,
recordkeeping, and reporting
requirements?
E. Summary of Major Changes Since
Proposal
IV. Additional Actions
A. Title V Permitting Requirements
B. Not Regulating This Source Category
Under CAA Section 112(c)(6)
V. Summary of Comments and Responses
A. Applicability
B. Selection of Regulatory Alternative
C. Bulk Terminals
D. Testing and Monitoring
E. Control Costs and Cost Analyses
Performed
F. Notifications, Reporting, and
Recordkeeping
VI. Summary of Environmental, Energy, Cost,
and Economic Impacts
A. What are the air impacts?
B. What are the cost impacts?
C. What are the economic impacts?
D. What are the non-air environmental and
energy impacts?
VII. 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
Risks and Safety Risks
H. Executive Order 13211: Actions
Concerning Regulations That
Significantly Affect Energy Supply,
Distribution, or Use
I. National Technology Transfer and
Advancement Act
J. Executive Order 12898: Federal Actions
To Address Environmental Justice in
Minority Populations and Low-Income
Populations
K. Congressional Review Act
I. General Information
A. Does this action apply to me?
The regulated categories and entities
affected by these final rules include:
Examples of regulated entities
Operations at area sources that transfer and store gasoline, including bulk terminals, bulk plants, pipeline facilities, and gasoline dispensing facilities.
Federal/State/local/tribal governments.
a North
American Industry Classification System.
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
PO 00000
Frm 00002
Fmt 4701
Sfmt 4700
E:\FR\FM\10JAR2.SGM
10JAR2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
This table is not intended to be
exhaustive, but rather provides a guide
for readers regarding entities likely to be
affected by the national emission
standards. To determine whether your
facility will be affected by the national
emission standards, you should
examine the applicability criteria in
these final rules. If you have any
questions regarding the applicability of
the national emission standards to a
particular entity, consult either the air
permit authority for the entity or your
EPA regional representative as listed in
40 CFR 63.13.
yshivers on PROD1PC62 with RULES2
B. Where can I get a copy of this
document?
In addition to being available in the
docket, an electronic copy of these final
rules is also available on the World
Wide Web through the Technology
Transfer Network (TTN). Following
signature, a copy of these final rules will
be posted on the TTN’s policy and
guidance page for newly proposed or
promulgated rules at the following
address: https://www.epa.gov/ttn/oarpg/.
The TTN provides information and
technology exchange in various areas of
air pollution control.
C. Judicial Review
Under section 307(b)(1) of the Clean
Air Act (CAA), judicial review of these
final rules is available only by filing a
petition for review in the United States
Court of Appeals for the District of
Columbia Circuit by March 10, 2008.
Under section 307(b)(2) of the CAA, the
requirements established by these final
rules may not be challenged separately
in any civil or criminal proceedings
brought by EPA to enforce these
requirements.
Section 307(d)(7)(B) of the CAA
further provides that ‘‘[o]nly an
objection to a rule or procedure which
was raised with reasonable specificity
during the period for public comment
(including any public hearing) may be
raised during judicial review.’’ This
section also provides a mechanism for
us to convene a proceeding for
reconsideration, ‘‘[i]f the person raising
an objection can demonstrate to the EPA
that it was impracticable to raise such
objection within [the period for public
comment] or if the grounds for such
objection arose after the period for
public comment (but within the time
specified for judicial review) and if such
objection is of central relevance to the
outcome of the rule.’’ Any person
seeking to make such a demonstration to
us should submit a Petition for
Reconsideration to the Office of the
Administrator, U.S. EPA, Room 3000,
Ariel Rios Building, 1200 Pennsylvania
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
Ave., NW., Washington, DC 20460, with
a copy to both the persons(s) listed in
the preceding FOR FURTHER INFORMATION
CONTACT section, and the Associate
General Counsel for the Air and
Radiation Law Office, Office of General
Counsel (Mail Code 2344A), U.S. EPA,
1200 Pennsylvania Ave., NW.,
Washington, DC 20460.
II. Background Information
On December 14, 1994 (59 FR 64303),
we promulgated national emission
standards for hazardous air pollutants
(NESHAP) for major source facilities
within the gasoline distribution source
category (see 40 CFR part 63, subpart R
(Major Source NESHAP)). The Major
Source NESHAP imposed control
requirements on sources within the
source category that met the definition
of major sources, e.g., a source that
emits 10 tons per year or more of any
individual hazardous air pollutant
(HAP) or 25 tons per year or more of any
combination of HAP. Gasoline vapors
normally contain nine HAP: benzene,
ethylbenzene, hexane, toluene, xylenes,
isooctane, naphthalene, cumene, and
methyl tert-butyl ether. Some gasoline
distribution terminals and pipeline
facilities were found to be major sources
by themselves or to be located at major
sources. Gasoline storage tanks at bulk
terminals and pipeline breakout
stations, loading racks at bulk terminals,
vapor leaks from gasoline cargo tanks,
and equipment components in gasoline
service were emission sources that were
regulated under the Major Source
NESHAP. Area sources of HAP
emissions within the source category
(many bulk terminals and pipeline
breakout stations and all pipeline
pumping stations, bulk plants, and
gasoline dispensing facilities (GDF)
(service stations, convenience stores,
and other retail outlets)) are not subject
to the Major Source NESHAP.
Section 112(k)(3)(B) of the CAA
requires EPA to identify at least 30 HAP
which, as the result of emissions from
area sources,1 pose the greatest threat to
public health in urban areas. Consistent
with this provision, in 1999, in the
Integrated Urban Air Toxics Strategy
(Strategy), EPA identified the 30 HAP
that pose the greatest potential health
threat in urban areas, and these HAP are
referred to as the ‘‘urban HAP.’’ See 64
FR 38706, 38715–716, July 19, 1999.
Section 112(c)(3) requires EPA to list
sufficient categories or subcategories of
area sources to ensure that area sources
representing 90 percent of the emissions
of the 30 urban HAP are subject to
1 An
area source is a stationary source of HAP
emissions that is not a major source.
PO 00000
Frm 00003
Fmt 4701
Sfmt 4700
1917
regulation. EPA listed the source
categories that account for 90 percent of
the urban HAP emissions in the
Strategy.2
CAA Section 112(d) standards include
new and existing source maximum
achievable control technology (MACT)
standards, health threshold standards,
and generally available control
technology or management practices
(GACT) standards for area sources. The
standards that are the subject of these
final rules are based on GACT pursuant
to CAA section 112(d)(5).
Gasoline vapors contain two HAP
(benzene and ethylene dichloride (EDC))
included among the 30 area source HAP
listed under the Strategy. The gasoline
distribution (Stage I) area source
category was listed in the Strategy
because the facilities in this category
contributed approximately 36 percent of
the national emissions of benzene and 2
percent of the EDC emissions from
stationary area sources. We are adding
two subparts to 40 CFR part 63 to
address the benzene emissions from the
facilities in this area source category. As
explained in the proposed rule, EDC
emissions are no longer emitted from
facilities in this area source category as
a result of the lead phase-down
provisions of section 218 of the CAA.
We received no comments on this
matter; therefore, we are taking no
further action regarding EDC emissions
in this rulemaking.
III. Summary of Final Rules and
Changes Since Proposal
This section summarizes the final
rules and identifies and discusses
changes since proposal. For changes
that were made as a result of public
comments, we have provided
explanations of the changes and the
rationale in the responses to comments
in section V of this preamble.
A. Applicability and Compliance Dates
These final rules apply to any existing
or new gasoline distribution facility that
is an area source. 40 CFR part 63,
subpart BBBBBB applies to bulk
gasoline terminals, pipeline facilities,
and bulk gasoline plants. 40 CFR part
63, subpart CCCCCC applies to GDF.
The owner or operator of an existing
area source must comply with all the
requirements of these final rules by
January 10, 2011. The owner or operator
of a new area source must comply with
these final rules by January 10, 2008 or
upon initial startup, whichever is later.
2 Since its publication in the Integrated Urban Air
Toxics Strategy in 1999, the area source category
list has undergone several amendments.
E:\FR\FM\10JAR2.SGM
10JAR2
yshivers on PROD1PC62 with RULES2
1918
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
B. Summary of Emission Limits and
Management Practices
40 CFR part 63, subpart BBBBBB
requires that area source bulk gasoline
terminals and pipeline breakout
stations 3 that meet the applicability
criteria in 40 CFR 63.11081 control
emissions from large storage tanks
(those at or above 20,000 gallons
capacity) by using either specified
floating roofs and seals or a closed vent
system and control device to reduce
emissions by 95 percent. Small storage
tanks (those below 20,000 gallons
capacity) must be covered.
40 CFR part 63, subpart BBBBBB also
requires that cargo tank loading rack
emissions located at bulk gasoline
terminals with gasoline throughputs
above 250,000 gallons per day be
reduced to a level of 80 milligrams (mg),
or less, per liter of gasoline loaded into
cargo tanks. Those bulk terminals with
gasoline throughputs below 250,000
gallons per day must use submerged
filling for the loading of cargo tanks.
Additionally, bulk terminal owners or
operators with gasoline throughputs
above 250,000 gallons per day must not
allow the loading of cargo tanks that do
not have the appropriate vapor tightness
testing documentation. Before loading at
an affected bulk terminal, the owner or
operator of a cargo tank must present
documentation of passing the vapor
tightness test to demonstrate, using EPA
Reference Method 27, or equivalent, that
they meet a maximum pressure or
vacuum decay rate of 3 inches of water,
or less, during a 5-minute test period.
At bulk plants, 40 CFR part 63,
subpart BBBBBB requires the use of
submerged filling of gasoline storage
tanks and cargo tanks.
40 CFR part 63, subpart BBBBBB also
requires the implementation of a
monthly equipment leak inspection at
bulk terminals, bulk plants, pipeline
breakout stations, and pipeline pumping
stations. The standards allow a sight,
sound, and smell inspection of all
equipment components in gasoline
liquid or vapor service. In the final rule,
all leaking equipment components must
be repaired within a specified time
period.
40 CFR part 63, subpart CCCCCC
requires controls at GDF nationwide
depending on the GDF’s monthly
gasoline throughput. All GDF must
perform specified good management
practices to check for and minimize
evaporation of gasoline. All those GDF
above 10,000 gallons per month
throughput must also employ
submerged filling of gasoline storage
3 See 40 CFR 63.11100 for the definitions of the
specific facilities regulated under subpart BBBBBB.
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
tanks. The submerged filling
requirement is met by either bottom
filling the storage tank or by using a fill
pipe to load the storage tank that
extends to no more than 12 inches from
the bottom of the storage tank for fill
pipes installed on or before November 9,
2006, and no more than 6 inches from
the bottom of the storage tank for fill
pipes installed after November 9, 2006.
Additionally, those GDF with a monthly
throughput of 100,000 gallons, or more,
must also use vapor balancing when
filling their gasoline storage tanks.
Additionally, under the final rule,
GDF that have tanks with a 250 gallon
capacity or less, regardless of monthly
throughput, are only required to
perform the good management practices
to check for and minimize evaporation
of gasoline described in section
63.11116(a); these tanks are not required
to comply with either the submerged fill
or vapor balancing requirements of the
final rule.
C. What are the testing and initial
compliance requirements?
40 CFR part 63, subpart BBBBBB
requires that control devices being used
to reduce emissions from loading racks
at bulk terminals be tested to
demonstrate that they comply with the
emission limit. Closed vent systems and
control devices used to reduce
emissions from storage tanks also have
to be tested to demonstrate that they
comply with the emission limit. Other
options for demonstrating compliance
with the rule include using recent
performance tests or providing
documentation that the devices are
complying with enforceable State, local,
or tribal rules or operating permits that
contain requirements at least as
stringent as this final rule.
Affected facilities that use control
devices (vapor processors) to comply
with the emission limits for storage
tanks or loading racks at bulk terminals
are required to monitor operating
parameters to demonstrate continuous
compliance with the emission limits.
The monitored operating parameter
values must be determined during a
performance test or by engineering
assessment. An operating parameter
monitoring approach approved by the
Administrator and included in an
enforceable operating permit is allowed
as an alternative.
Annual inspections of storage tank
roofs and seals are required for bulk
terminals and pipeline breakout
stations. Such inspections must be
conducted using either the procedures
required in 40 CFR part 60, subpart Kb,
Standards of Performance for Volatile
Organic Liquid Storage Vessels (Storage
PO 00000
Frm 00004
Fmt 4701
Sfmt 4700
Vessels New Source Performance
Standards (NSPS)) or the procedures
required in 40 CFR part 63, subpart WW
(National Emission Standards for
Storage Vessels (Tanks)—Control Level
2).
In addition, each owner or operator of
a bulk gasoline terminal is required to
monitor the loading of gasoline into
gasoline cargo tanks to limit the loading
to vapor-tight gasoline cargo tanks. The
owner or operator of each gasoline cargo
tank loading at an affected bulk terminal
is required to perform vapor tightness
testing on each cargo tank to
demonstrate compliance with the
maximum allowable pressure and
vacuum change of 3 inches of water, or
less, in 5 minutes. Vapor tightness
testing must be performed using EPA
Reference Method 27. Railcar cargo
tanks may also use the ‘‘Railcar Bubble
Leak Test Procedures’’ specified in the
rule.
40 CFR part 63, Subpart CCCCCC
requires that the owner or operator of
GDF meeting the applicability criteria
for vapor balancing demonstrate initial
compliance with this emission limit by
conducting an initial performance test
on the vapor balance system. The rule
also contains other options for
demonstrating compliance with this
emission limit, such as using recent
performance tests or providing
documentation that the vapor balance
systems are complying with enforceable
State, local, or tribal rules or operating
permits that contain requirements at
least as stringent as this final rule.
Each owner or operator must also
determine, at the time of installation
and every 3 years thereafter, the leak
rate and cracking pressure of pressurevacuum vent valves installed on
gasoline storage tanks and must conduct
a static pressure test on gasoline storage
tanks.
D. What are the notification,
recordkeeping, and reporting
requirements?
Affected sources that are subject to
the control requirements under these
final rules are required to submit four
types of notifications or reports as set
forth in the General Provisions: (1)
Initial Notification; (2) Notification of
Compliance Status; (3) periodic reports;
and (4) other reports. The Initial
Notification alerts the regulatory
authority of applicability for existing
sources or of construction for new
sources. This notification also includes
a statement as to whether the facility
can achieve compliance by the required
compliance date. The Notification of
Compliance Status demonstrates that
compliance has been achieved. This
E:\FR\FM\10JAR2.SGM
10JAR2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
yshivers on PROD1PC62 with RULES2
notification contains the results of
initial performance tests and a list of
equipment subject to the standard.
Periodic reports are required on a semiannual basis. The semi-annual
compliance report informs the
regulatory authority of the results of
required inspections or additional
testing results. An excess emissions
report, if applicable, must be submitted
with the semi-annual compliance report
and is required if excess emission
events occur. Excess emission events
include events such as the loading of a
cargo tank that does not have
documentation of vapor tightness
testing, deviations from acceptable
operating parameter values, or
equipment leaks that are not repaired
within the required time.
Other reports are also required under
the General Provisions, generally on a
one-time basis, for events such as a
notification before a performance test or
a storage vessel inspection. Reporting
these events allows the regulatory
authority the opportunity to have an
observer present.
Reporting requirements for owners or
operators of bulk plants and GDF are
limited in most cases to the Initial
Notification and the Notification of
Compliance Status. Those bulk plants
that are located in States that require the
use of submerged fill would not be
required to submit these notifications.
The same is true for GDF located in
States or counties that already require
submerged fill or submerged fill plus
vapor balancing.
Records required under these final
rules must be kept for 5 years. These
include records of cargo tank vapor
tightness test certifications, records of
storage tank and equipment component
inspections, and records of monthly
throughput.
E. Summary of Major Changes Since
Proposal
As a result of the public comments
received in response to the November 9,
2006 proposal, we have made several
changes in the final rules for this source
category. This section presents a
summary of the major changes since
proposal. Additional discussion of the
details of the changes and the rationale
for making these changes is presented in
section V of this preamble.
As proposed, 40 CFR part 63, subpart
BBBBBB applied to both bulk facilities
nationwide and GDF in Urban 1 and
Urban 2 areas. We also requested
comment on whether to require vapor
balancing at GDF in Urban 1 areas and
provided rule text in the docket. In
order to simplify the final rules, we
have included the requirements for bulk
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
facilities in subpart BBBBBB and have
included all requirements for GDF in a
separate subpart (40 CFR part 63,
subpart CCCCCC).
We have made some changes to the
requirements for bulk facilities. Internal
floating roof storage tanks at bulk
terminals and pipeline breakout stations
will not have to be equipped with
secondary rim seals (as proposed) if
they have vapor mounted primary seals.
Also, we are clarifying that storage tanks
below 20,000 gallons in capacity require
a cover, and those at or above 20,000
gallons in capacity require the controls
as proposed and mentioned above.
We have also made some changes to
the requirements for loading racks at
bulk terminals. We proposed a
requirement that all bulk terminals meet
an 80 mg per liter (mg/l) emission
standard for loading racks. Based on
comments received, however, the type
of control required in the final rule
depends on the daily gasoline
throughput of the bulk terminal.
Loading racks at bulk terminals with
daily gasoline throughputs of less than
250,000 gallons are required to use
submerged filling; those at or above a
daily gasoline throughput of 250,000
gallons are required to meet the 80 mg/
l standard.
Additionally, we requested comment
and supporting information on
alternative parameter monitoring
approaches for vapor processors used to
meet the 80 mg/l standard for bulk
terminal loading racks. After
consideration of the public comments,
we have decided to include presence of
flame monitoring (as was proposed) for
thermal oxidizers, and vacuum level
monitoring for carbon adsorbers, as
alternatives for monitoring the
performance of vapor processors. We
also took comments and requested data
on additional requirements for these
alternative monitoring approaches. We
have incorporated these additional
periodic equipment and maintenance
inspections of the vapor processor
systems into the final rule.
No major changes since proposal have
been made to the requirements for
pipeline facilities or bulk plants.
For GDF (40 CFR part 63, subpart
CCCCCC), we have incorporated
changes to the submerged fill
requirements and the vapor balance
requirements on which we requested
comments. The final rule contains
specific requirements for GDF
nationwide depending on the GDF’s
monthly gasoline throughput. All GDF,
regardless of size, must implement
management practices that will
minimize vapor releases to the
atmosphere. GDF with a monthly
PO 00000
Frm 00005
Fmt 4701
Sfmt 4700
1919
gasoline throughput of 10,000 gallons or
more must also use submerged fill when
loading their storage tanks. In addition
to the requirements described above,
GDF with a monthly gasoline
throughput of 100,000 gallons or more
must use vapor balancing when loading
the storage tank. Subpart CCCCCC also
contains requirements applicable to
gasoline cargo tanks.
IV. Additional Actions
In today’s final rulemaking, we are
also finalizing two additional actions
that were announced at proposal. These
final actions address title V permit
requirements and our decision not to
regulate the gasoline distribution (Stage
I) area source category under CAA
section 112(c)(6).
A. Title V Permitting Requirements
Section 502(a) of the CAA provides
that EPA may exempt one or more area
source categories from the requirements
of title V if the Administrator finds that
compliance with such requirements is
‘‘impracticable, infeasible, or
unnecessarily burdensome’’ on such
categories. EPA must determine whether
to exempt an area source from title V at
the time we issue the relevant CAA
section 112 standard (40 CFR
70.3(b)(2)). In this action, we are
finalizing the proposed exemption of
gasoline distribution area sources from
the requirement to apply for and obtain
a title V permit as a result of being
subject to these final rules. We justified
this finding at proposal and did not
receive any negative comments during
the public comment period regarding
this issue. In fact, we received two
positive comments supporting the
exemption. As a result, gasoline
distribution area sources are not
required to obtain title V permits
because of being subject to these final
rules. However, if such sources are
otherwise required to obtain title V
permits, e.g., due to being part of a
major source defined under title V (40
CFR 70.2, 40 CFR 71.2, and 40 CFR
63.2), they must apply for and obtain
title V permits. The applicability criteria
for title V are in 40 CFR 70.3(a) and (b)
and 40 CFR 71.3(a) and (b). We are
adding additional regulatory text to this
rule to clarify the above.
B. Not Regulating This Source Category
Under CAA Section 112(c)(6)
On November 8, 2002 (67 FR 68124),
the Gasoline Distribution (Stage I) Area
Source category was added to the list of
source categories for development of
standards under CAA section 112(c)(6)
toward the 90-percent requirement for
polycyclic organic matter (POM). One
E:\FR\FM\10JAR2.SGM
10JAR2
1920
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
surrogate for POM is the sum of 16
polynuclear aromatic hydrocarbon
compounds (16–PAH) measured in EPA
Test Method 610. Naphthalene is the
only 16–PAH estimated and reported in
the 1990 inventory that is emitted from
gasoline distribution facilities. As
explained in the proposal preamble, we
have revised the 1990 inventory of
naphthalene from this source category
downward based on additional data
received. Based on that information, we
have concluded that gasoline
distribution facilities (area sources)
contribute only 0.02 percent of the total
16-PAH (1.73 tons out of 8,051 tons) and
are not needed to meet the 90-percent
requirement for POM in CAA section
112(c)(6). This action finalizes our
decision not to regulate this source
category under CAA section 112(c)(6)
since we fully justified this conclusion
at proposal and did not receive any
negative comments at proposal.
V. Summary of Comments and
Responses
The gasoline distribution area source
rules were proposed on November 9,
2006 (71 FR 66064). The 60-day public
comment period ended on January 8,
2007, and we received 36 comment
letters. Comments were received from
industry representatives, trade
associations, State and local air
pollution control agencies,
environmental groups, air pollution
control device vendors, and private
citizens. The final rules reflect our
consideration of all of the comments
received on the proposed action. This
section summarizes the significant
comments and those that resulted in
changes in the final rules. Our responses
to comments not specifically addressed
in this preamble are presented in the
Response to Comments Document,
which is available in Docket No. EPA–
HQ–OAR–2006–0406.
A. Applicability
yshivers on PROD1PC62 with RULES2
1. Area Sources
Comment: One commenter questioned
whether EPA intended the area source
rules to apply to facilities that are major
sources and that have GDF on site for
refueling of their vehicles (fleet vehicle
refueling centers). Another commenter
stated that EPA should clarify that the
proposed rule does not apply to gasoline
distribution major sources.
Response: The gasoline distribution
(Stage I) area source rules apply to those
gasoline distribution facilities that
qualify as area sources. Facilities that
are major sources (emit ≥ 10 tons per
year of one HAP or emit ≥ 25 tons per
year of any combination of HAP) as a
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
result of their gasoline distribution
activities, or as a result of any other
activities, would not be subject to these
final area source rules. We have
clarified in the final rules that these
rules only apply to area sources.
2. GACT Versus MACT Approach
Comment: One commenter stated that
EPA’s own interpretation of CAA
section 112(d)(5) allowed it to set GACT
standards ‘‘when the imposition of
MACT is determined to be
unreasonable,’’ (60 FR 4948, 4953,
January 25, 1995) and that because EPA
did not offer any technological or
economic reasons why MACT was
unreasonable for this source category,
the selection of GACT rather than
MACT was arbitrary and capricious.
Response: EPA disagrees with the
commenter’s assertion. The commenter
has taken the phrase cited above in a
prior Federal Register notice out of
context and erroneously asserts that
EPA must first justify why it is not
setting a MACT standard before it can
issue a GACT standard for a particular
area source category.
In the Federal Register notice cited
above, EPA promulgated final rules
limiting the discharge of chromium
compound emissions from both major
sources and area sources in the hard
chromium electroplating, decorative
chromium electroplating and chromium
anodizing tanks source categories. In
developing that rulemaking, we first
established the MACT standards for the
major sources in each source category.
Once we determined the standards for
major sources, which must be based on
MACT, we then evaluated what the
standards should be for area sources. At
that time, EPA recognized that it had
authority to issue GACT standards for
area sources. In determining what was
GACT for those area sources, EPA
considered the standards it had just set
for the major sources and evaluated the
technical feasibility of imposing the
major source requirements on the area
sources.
Additionally, since EPA could
consider cost in setting a GACT
standard, EPA also evaluated whether
the cost of imposing the major source
standards on the area sources in those
source categories would be reasonable.
The statements in the prior Federal
Register notice concerning CAA section
112(d)(5) were focused on the factual
circumstances of that rule, which
involved the simultaneous
promulgation of major and area source
standards. We did not, in that
rulemaking, conduct a thorough
analysis of the requirements for setting
PO 00000
Frm 00006
Fmt 4701
Sfmt 4700
a GACT standard under CAA section
112(d)(5).
As recognized in the Federal Register
notice cited above, and in this final rule,
Congress gave EPA explicit authority to
issue alternative emission standards for
area sources in section 112(d)(5) of the
CAA. Specifically, CAA section
112(d)(5), which is entitled ‘‘Alternative
standard for area sources,’’ provides:
With respect only to categories and
subcategories of area sources listed pursuant
to subsection (c) of this section, the
Administrator may, in lieu of the authorities
provided in paragraph (2) and subsection (f)
of this section, elect to promulgate standards
or requirements applicable to sources in such
categories or subcategories which provide for
the use of generally available control
technologies or management practices by
such sources to reduce emissions of
hazardous air pollutants. (Emphasis added.)
There are two critical aspects to CAA
section 112(d)(5). First, CAA section
112(d)(5) applies only to those
categories and subcategories of area
sources listed pursuant to CAA section
112(c). The commenter does not dispute
that EPA listed the Gasoline
Distribution (Stage I) Area Source
category pursuant to CAA section
112(c)(3). Second, CAA section
112(d)(5) provides that for area sources
listed pursuant to CAA section 112(c),
EPA ‘‘may, in lieu of ’’ the authorities
provided in CAA section 112(d)(2) and
112(f), elect to promulgate standards
pursuant to CAA section 112(d)(5). CAA
Section 112(d)(2) provides that emission
standards established under that
provision ‘‘require the maximum degree
of reduction in emissions’’ of HAP (also
known as MACT). CAA Section
112(d)(3), in turn, defines what
constitutes the ‘‘maximum degree of
reduction in emissions’’ for new and
existing sources. See CAA section
112(d)(3).4 Webster’s dictionary defines
the phrase ‘‘in lieu of’’ to mean ‘‘in the
place of’’ or ‘‘instead of.’’ See Webster’s
II New Riverside University (1994).
Thus, CAA section 112(d)(5) authorizes
EPA to promulgate standards under
CAA section 112(d)(5) that provide for
the use of generally available control
4 Specifically, section 112(d)(3) sets the minimum
degree of emission reduction that MACT standards
must achieve, which is known as the MACT floor.
For new sources, the degree of emission reduction
shall not be less stringent than the emission control
that is achieved in practice by the best-controlled
similar source, and for existing sources, the degree
of emission reduction shall not be less stringent
than the average emission limitation achieved by
the best-performing 12 percent of the existing
sources for which the Administrator has emissions
information. CAA section 112(d)(2) directs EPA to
consider whether more stringent—so called beyondthe-floor limits—are technologically achievable
considering, among other things, the cost of
achieving the emission reduction.
E:\FR\FM\10JAR2.SGM
10JAR2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
yshivers on PROD1PC62 with RULES2
technologies or management practices
(GACT), instead of issuing MACT
standards pursuant to CAA section
112(d)(2) and (d)(3). The statute does
not set any condition precedent for
issuing standards under section
112(d)(5) other than that the area source
category or subcategory at issue must be
one that EPA listed pursuant to CAA
section 112(c), which is the case here.5
The commenter argues that EPA must
provide a rationale for why issuing
MACT standards for this area source
category is ‘‘unreasonable’’ before it can
issue GACT standards under CAA
section 112(d)(5). The commenter is
incorrect, however. Had Congress
intended that EPA first conduct a MACT
analysis for each area source category,
and only if cost or some other reason
made applying the MACT standard
‘‘unreasonable’’ for the category would
EPA be able to issue a standard under
CAA section 112(d)(5), Congress would
have stated so expressly in CAA section
112(d)(5). Congress did not require EPA
to conduct any MACT analysis, floor
analysis, or beyond-the-floor analysis
before the Agency could issue a CAA
section 112(d)(5) standard. Rather,
Congress authorized EPA to issue GACT
standards for area source categories
listed under CAA section 112(c)(3), and
that is precisely what EPA has done in
this rulemaking.
Although EPA has no obligation to
justify why it is issuing a GACT
standard for an area source category as
opposed to a MACT standard, EPA must
set a GACT standard that is consistent
with the requirements of CAA section
112(d)(5) and have a reasoned basis for
its GACT determination. In determining
what constitutes GACT for a particular
area source category, EPA evaluates the
control technologies and management
practices that reduce HAP emissions
that are generally available for the area
source category.6 The legislative history
supporting CAA section 112(d)(5)
provides that EPA may consider costs in
determining what constitutes GACT for
the area source category.7 EPA cannot
5 CAA section 112(d)(5) also references CAA
section 112(f). See CAA section 112(f)(5) (entitled
‘‘Area Sources’’ and providing that EPA is not
required to conduct a review or promulgate
standards under CAA section 112(f) for any area
source category or subcategory listed pursuant to
CAA section 112(c)(3) and for which an emission
standard is issued pursuant to CAA section
112(d)(5)).
6 As explained above, in developing GACT for the
area sources subject to this rule, EPA analyzed both
the control technologies and management practices
used by area sources in the category to reduce HAP
and the control approaches employed by the major
sources in this category to reduce HAP.
7 Additional information on the definition of
‘‘generally available control technology or
management practices’’ (GACT) is found in the
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
consider cost in setting MACT floors,
pursuant to CAA section 112(d)(3). Area
sources differ from major sources,
which is why Congress permitted EPA
to consider costs in setting GACT
standards for area sources under CAA
section 112(d)(5), but did not permit
that consideration in setting MACT
floors for major sources. This important
dichotomy between CAA section
112(d)(3) and CAA section 112(d)(5)
provides further evidence that Congress
sought to do precisely what the title of
CAA section 112(d)(5) states—provide
EPA the authority to issue ‘‘[a]lternative
standards for area sources.’’ EPA
properly issued standards for this area
source category under CAA section
112(d)(5), and as demonstrated below,
EPA has a reasoned basis for each of its
GACT determinations.
Finally, even accepting, for arguments
sake, the commenter’s assertion that
EPA must provide a rational basis for
setting a GACT standard as opposed to
a MACT standard, we did so in the
proposed rule. In the proposal, we
explained that we can and do consider
costs and economic impacts in
determining GACT. We also explained
that the facilities in the source
categories at issue here are already well
controlled for the Urban HAP for which
the source category was listed pursuant
to CAA section 112(c)(3). We believe the
consideration of costs and economic
impacts is especially important for the
well-controlled facilities in this area
source category because, given current
well-controlled levels, a MACT floor
determination, where costs cannot be
considered, could result in only
marginal reductions in emissions at very
high costs for modest incremental
improvement in control for this area
source category.
Comment: One commenter
encouraged EPA to reevaluate GACT
based on the cost-effectiveness of
controls for volatile organic compounds
(VOC) as a function of the source’s
throughput instead of using the costeffectiveness of controls for benzene.
The commenter believes doing so would
demonstrate that more stringent
emission standards and monitoring
requirements (similar to the MACT) are
warranted for all but the smallest of
facilities. The commenter pointed out
that in 1980, when EPA developed the
Senate report on the 1990 amendments to the CAA
(S. Rep. No. 101–228, 101st Cong. 1st session, 171–
172). That report states that GACT is to encompass:
* * * Methods, practices, and techniques which
are commercially available and appropriate for
application by the sources in the category
considering economic impacts and the technical
capabilities of the firms to operate and maintain the
emissions control systems.
PO 00000
Frm 00007
Fmt 4701
Sfmt 4700
1921
Control Technique Guidelines (CTG) for
VOC control in ozone non-attainment
areas, $2,000 per ton was considered
reasonably available control technology
(RACT). With inflation over the past 26
years, it should be in the range of $6,000
per ton. According to the commenter,
since benzene constitutes only about 1
percent of the VOC emissions, the costeffectiveness of these controls for VOC
will be about 100 times better. The
commenter prefers applicability
thresholds based on throughput, rather
than geographical boundaries, as
proposed. The commenter believes that
the proposed GACT neglects
consideration of the risk posed by
individual sources to the local
communities. The commenter also
encouraged EPA to consider more
stringent requirements for ‘‘new
sources.’’
Another commenter pointed out that,
in addition to benzene exposure, VOC
from gasoline fueling play a role in the
formation of ground level ozone (smog).
The commenter stated that EPA should
consider the full scope of air pollution
concerns that are affected by emissions
from gasoline distribution and should
design its Stage I regulations to
maximize the amount of reductions
achieved for both air toxics and ozone
precursor emissions.
Response: We understand the
commenters’ desires for achieving
greater VOC emission reductions in this
rulemaking. We agree that VOC
emissions contribute to other air
pollution concerns and appreciate the
State and local agencies’ efforts in
addressing these emissions through
their regulatory programs. We also agree
that an analysis of the impacts of this
rule based strictly on the control of VOC
would yield different cost-effectiveness
values and potentially support requiring
more stringent control technologies for
these facilities. In fact, we did calculate
VOC impacts during our analysis of the
proposed and final regulatory
alternatives and these values are
presented in the supporting
documentation. But, as explained in
other sections of this preamble, the
primary focus of these area source rules
is fulfilling our obligations under CAA
section 112(c)(3) for regulating
stationary sources of benzene. While the
controls finalized today will achieve
reductions in both HAP and VOC
emissions, we appropriately focused on
the HAP cost-effectiveness values in
determining what is GACT for facilities
in this area source category.
Based on comments received, we have
reconsidered the use of gasoline
throughput for determining what is
GACT for these facilities and have
E:\FR\FM\10JAR2.SGM
10JAR2
1922
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
yshivers on PROD1PC62 with RULES2
incorporated multiple throughputs into
the final rules. The final rules require
controls at affected facilities
nationwide, thus, addressing the
impacts of benzene emissions from this
area source category regardless of
geographical boundaries.
In the final rules we distinguish
between new and existing sources for
the submerged fill requirements
applicable to bulk gasoline plants and
GDF. See 40 CFR 63.11086, 40 CFR
63.11117, and 40 CFR 63.11118 for the
specific requirements. Control
requirements at the remaining facilities
(bulk gasoline terminals, pipeline
breakout stations, and pipeline pumping
stations) apply equally to both new and
existing sources.
3. Proposed Exemptions
Comment: One commenter stated that
CAA section 112(d)(5) does not
authorize EPA to base GACT decisions
on whether it believes that control
technologies are or are not cost-effective
but, rather, intended EPA to consider
‘‘economic impacts.’’ Therefore, EPA’s
decision not to require a control level of
35 mg/l for loading racks, 1-inch
pressure drop testing for cargo tanks,
and vapor balancing of storage tanks at
bulk plants and GDF, based on costeffectiveness rather than technological
or economic impact issues, is unlawful.
Response: We disagree with the
commenter’s interpretation that CAA
section 112(d)(5) does not authorize
EPA to consider cost-effectiveness as
well as economic impacts in
determining what is GACT for the
affected facilities in an area source
category. The legislative history
supporting CAA section 112(d)(5)
provides that EPA may consider costs in
determining what constitutes GACT for
the area source category (see footnote 7).
Area sources differ from major sources,
which is why Congress permitted EPA
to consider costs, including costeffectiveness, in setting GACT standards
for area sources under CAA section
112(d)(5), but did not permit that
consideration in setting MACT floors for
major sources. The commenter did not
cite any specific language in the CAA
that prevents us from considering costeffectiveness as well as other economic
impacts in determining the level of
control that constitutes GACT for an
area source category. We believe EPA
properly considered cost-effectiveness
in each of its GACT determinations for
this area source category under CAA
section 112(d)(5). See also Husqvarna
AB v. EPA, 349 U.S. App. D.C. 118, 254
F.3d 195, 201 (DC Cir. 2001) (finding
EPA’s decision to consider costs on a
per ton of emissions removed basis
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
reasonable because CAA section 213 did
not mandate a specific method of cost
analysis).
Comment: One commenter stated that
because the CAA requires standards for
all sources in a category, EPA’s refusal
to set standards for storage tanks with a
capacity less than 20,000 gallons is
unlawful. The commenter stated that
EPA does not claim that no control
technology is generally available for
storage tanks with a capacity less than
20,000 gallons or provide any reason
that they cannot employ the same
technology that is used by larger storage
tanks.
Response: In response to this
comment, EPA reexamined its GACT
determination for storage tanks with a
capacity less than 20,000 gallons. As
explained above, determining what
constitutes GACT involves considering
the control technologies and
management practices that are generally
available to the facilites in the area
source category. We also consider
standards applicable to major sources in
the same industrial sector to determine
if the control technologies and
management practices are transferable
and generally available to area sources.
We further consider the costs and
economic impacts of available control
technologies and management practices
on that source category.
In the proposed and final rule, we
distinguished storage tanks based on
size and developed a 20,000 gallon
capacity threshold. This size threshold
is similar to the threshold used in
several other standards that apply to
storage tanks, including 40 CFR part 60,
subpart Kb and the Gasoline
Distribution Major Source NESHAP. As
explained in the 1994 ‘‘Alternative
Control Techniques Document: Volatile
Organic Liquid Storage in Floating and
Fixed Roof Tanks’’ (EPA–453/R–94–
001), 20,000 gallons is generally
considered to be the breakpoint between
horizontal and vertical tanks. The
document reports that most storage
tanks below 20,000 gallons are
horizontal rather than vertical and a
large percentage of these tanks are also
underground tanks.
In the final rule, we are requiring
storage tanks with a capacity of 20,000
gallons or more to have floating roof and
seal technologies. In response to this
comment, we re-evaluated the
application of these same controls on
tanks with a capacity less than 20,000
gallons and determined that these
control approaches do not represent
GACT for tanks with a capacity less
than 20,000 gallons. First, for horizontal
tanks, which are generally tanks with a
capacity below 20,000 gallons, the
PO 00000
Frm 00008
Fmt 4701
Sfmt 4700
floating roof technology is not
technically feasible. Horizontal tanks do
not have perpendicular sides; this
precludes the application of floating
roof technology to these tanks. Second,
our analysis shows that the costeffectiveness of requiring the
application of floating roof technology
to vertical storage tanks below the
20,000 gallon size is, at best, about
$8,000 per ton of HAP.
Instead, in the final rule, we are
requiring that facilities using storage
tanks with a capacity below 20,000
gallons follow certain management
practices for controlling emissions. See
40 CFR 63.11087 for those specific
requirements.
Comment: One commenter believes it
is not necessary to regulate GDF that are
already using submerged fill, especially
when required by an enforceable State,
local, or tribal rule or permit. The
commenter believes that facilities
already have safety, economic, and
environmental reasons to minimize
spills, clean them up quickly, and
prevent gasoline from remaining in the
environment; thus, according to the
commenter, additional emission
reductions achieved by including these
management practices in the final rule
might not be significant. The commenter
recommends that EPA evaluate the
potential for emission reductions
achievable by requiring these
management practices and, if minimal
emission reductions would result, EPA
could either entirely exclude tanks
already equipped with a submerged fill
system, or exclude tanks covered by a
submerged fill requirement in an
enforceable State, local, or tribal rule or
permit. In either case, the commenter
suggests that the provision in the
proposed 40 CFR 63.11085(f) would
become an exclusion in the proposed 40
CFR 63.11081.
Another commenter believes that GDF
should be excluded from any and all
proposed and final regulatory
alternatives because most States/regions
with unacceptable levels of VOC and
HAP already require Stage I controls
which include submerged filling of
underground storage tanks. The
commenter believes that including GDF
in the applicability of the proposed rule
will inordinately increase the amount of
paperwork (requiring the submittal of
Initial Notifications and Notification of
Compliance Status to dozens of States
and local agencies) with little to no
environmental benefit. The commenter
believes that GDF should be regulated at
the State and local level as they are
today.
Response: By suggesting that we
should not set Federal emission
E:\FR\FM\10JAR2.SGM
10JAR2
yshivers on PROD1PC62 with RULES2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
standards, the commenters ignore the
language of the statute. The CAA
requires that EPA set Federal emission
standards under CAA section 112(d) for
source categories listed under CAA
section 112(c)(3), and that is precisely
what we are doing here. GDF are
affected facilities within the gasoline
distribution (Stage I) area source
category. These facilities formed part of
the basis for listing this area source
category; hence, EPA is promulgating
rules regulating emissions from these
facilities. As summarized in section III.B
of this preamble, 40 CFR part 63,
subpart CCCCCC requires controls at
GDF nationwide depending on their
monthly gasoline throughput. All GDF
must employ certain management
practices. GDF with monthly
throughput of 10,000 gallons or more
must use submerged fill when loading
their storage tanks. GDF with a monthly
throughput of 100,000 gallons or more
must also install a vapor balance
system. These controls are GACT for
these facilities in this area source
category.
We agree with the concept of reducing
the reporting and recordkeeping burden
on affected facilities. We have taken
steps in the proposed and final rules to
minimize these burdens by not
requiring notifications or reports from
facilities that are already operating in
compliance with enforceable State,
local, or tribal rules and permits that
include requirements that are at least as
stringent as those contained in these
final rules.
Comment: Two commenters support
exempting bulk plants and pipeline
pumping facilities because emissions
from pipeline pumping stations are
insignificant and because the
recordkeeping and reporting would
represent a burden with no benefit. The
commenters stated that if EPA does not
agree to fully exempt bulk plants and
pipeline pumping stations, at the very
least, those facilities that do not have a
storage tank or loading rack subject to
controls should be exempted from the
equipment leak requirements.
Response: As explained above, by
suggesting that we should not set
Federal emission standards for these
facilities, the commenters ignore the
language of the statute. The CAA
requires that EPA set Federal emission
standards under CAA section 112(d) for
source categories listed under CAA
section 112(c)(3), and that is precisely
what we are doing here. Bulk plants and
pipeline pumping stations are affected
facilities within the Gasoline
Distribution (Stage I) Area Source
category. These facilities formed part of
the basis for listing this area source
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
category; hence, EPA is promulgating
rules regulating emissions from these
facilities. As such, 40 CFR part 63,
subpart BBBBBB includes requirements
for controls at these facilities based on
what EPA determined was GACT for
each facility.
We have, however, taken steps to
reduce the reporting and recordkeeping
burden on these facilities. The
requirement to submit a combined
Initial Notification/Notification of
Compliance Status is the only routine
reporting requirement imposed on these
facilities. No periodic reports are
required as part of the equipment leak
inspection program as long as leaks are
repaired in a timely manner. We believe
that the potential safety and
environmental benefits of an equipment
leak inspection program justify the
minimal expense involved.
4. Nationwide Coverage Versus Urban
Area Coverage for Standards
Comment: Several commenters stated
that they were strongly opposed to
EPA’s intended approach to narrow the
application of CAA section 112(d) area
source rules to urban areas, while other
commenters were opposed to
broadening the applicability of the rules
to all areas.
One commenter stated that because
CAA section 112 does not authorize
EPA to decline to set standards for any
sources within a category of sources that
it has listed pursuant to CAA section
112(c), the threshold for sources that are
not in urban areas (as well as those
below the proposed size applicability
thresholds) would be unlawful.
One commenter stated that there is
little justification apparent in the
proposed rule for mandating submerged
fill for loading of storage tanks in nonurban areas. The commenter claimed
that to do so would result in additional
costs to GDF, while achieving minimal
reductions in emissions. The
commenter stated that, as a matter of
law, the Agency’s discretion is limited
to imposing area source controls to area
sources located within urban areas.
One commenter believes that EPA
should apply the rule in accordance
with the expressed intent of Congress,
which was to reduce ‘‘risks to public
health in urban areas.’’ Therefore,
according to this commenter, the rule
should apply only to facilities that are
located in or near urban areas. The
commenter also stated that health risk
should be taken into account in
evaluating cost-effectiveness, and riskdistance issues should be considered.
The commenter provided an analysis of
their recommended use of a risk-
PO 00000
Frm 00009
Fmt 4701
Sfmt 4700
1923
distance look-up table to determine
applicability of the rule.
Other commenters stated that
regardless of whether residential
populations are urban or rural,
individuals living in close proximity to
GDF are subjected to elevated exposures
to HAP and, given the trend of building
very high volume throughput GDF, the
level of exposure is likely to remain
high and even increase.
One commenter urged EPA to follow
conventional approaches in determining
the scope of controls, and, in so doing,
apply proposed Regulatory Alternatives
(RA) 2 and 3 to all counties nationwide.
The commenter urges EPA in this
rulemaking, and in future area source
rulemakings, to apply area source
standards uniformly in all counties
nationwide, particularly in
circumstances where the area source
category is ubiquitous, as is the case
with gasoline distribution.
Another commenter stressed that the
impacts of emissions from gasoline
distribution and dispensing facilities are
localized and would be similar for most
urban and rural areas. The commenter
stated that the cost of controlling these
facilities would be the same in rural or
urban settings as well; therefore,
because the costs and environmental
impacts are the same, there does not
appear to be any rationale for treating
rural and urban facilities differently.
One commenter stated that the fact
that some State and local agencies
already regulate these sources does not
relieve EPA of its obligation to reduce
emissions under CAA section 112.
According to another commenter, many
State and local agencies cannot be more
stringent than the Federal government.
The commenter further stated that once
a Federal rule is promulgated, some
agencies must change their regulations
to make them consistent with those of
the Federal government, which could
result in backsliding if the State or local
rule was more stringent to begin with.
Two comments expressed opposition
to limiting the geographic scope of the
proposed regulatory alternatives to
reduce the ‘‘overall cost of the rule.’’
Response: After consideration of all
comments related to the issue of
nationwide versus urban applicability of
the proposed standards for submerged
fill and vapor balancing at GDF
(proposed RA 2 and 3), we believe a
nationwide approach is appropriate
given the facts and circumstances of this
particular area source category. As
suggested by commenters, the final rule
requires GDFs nationwide to control
HAP emissions, and those control
requirements differ depending on the
monthly throughput of the GDF, which
E:\FR\FM\10JAR2.SGM
10JAR2
yshivers on PROD1PC62 with RULES2
1924
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
is a reasonable factor for distinguishing
between GDF. As explained in other
responses and sections of this preamble,
the final rule requires all GDF,
regardless of size, to implement certain
management practices to reduce vapor
evaporation. Additionally, GDF with a
monthly throughput of 10,000 gallons or
more must use submerged fill, while
GDF with a monthly throughput of
100,000 gallons or more must install
vapor balance systems.
As proposed, the rule would have
only required controls at GDF located in
Urban 1 and Urban 2 areas. Some
commenters suggested further
narrowing the applicability of the rule
to GDF based on the health risks and
distance to the population of individual
facilities. However, facilities located in
Urban 1 and Urban 2 areas were the
basis for listing area source categories
pursuant to section 112(c)(3) of the
CAA. We are currently under courtordered deadlines to complete issuing
standards for all listed area source
categories. Changing our focus would
mean recreating an area source category
list which may differ significantly from
the current list, greatly hindering our
effort to complete our obligation by the
court-ordered deadlines. Therefore, we
believe that revisiting the basis for
listing the area source categories is
inappropriate at this time. And, as
further explained below, we believe the
particular facts for this area source
category indicate that GDF nationwide
should implement controls based on
their monthly gasoline throughput.
We believe that the CAA provides the
Agency with the authority to regulate
area sources nationwide. As explained
in the Strategy and the proposed rule,
we interpret these provisions as
providing EPA authority to regulate
listed area source categories on a
nationwide basis. Indeed, in several
other area source rules, EPA has
exercised this discretion and issued
rules of nationwide applicability, as it
has done here. See, e.g., 72 FR 26
(January 3, 2007); 72 FR 2930 (January
23, 2007); 72 FR 38864 (July 16, 2007).
A rule of nationwide applicability is
particularly appropriate here because
control costs are not expected to differ
in rural vs. urban settings, so the
control’s cost-effectiveness is the same,
and economic impacts are equally
distributed. In addition, after reviewing
the public comments and the additional
analyses presented in support of those
comments, we determined that the
controls discussed above are
commercially available as they are being
used by many bulk facilities and GDF,
and they are cost-effective (considering
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
the source type and size thresholds
noted above) for bulk facilities and GDF.
Therefore, consistent with CAA
section 112(d)(5), the final rule
establishes standards that reflect the
application of generally available
control technology or management
practices, and we properly considered
cost-effectiveness and other economic
impacts in determining what constitutes
GACT for this area source category.
The commenter also suggested that
we should consider health risks in
making our GACT determination for
each facility. In the 1990 CAA
Amendments, Congress established a
two-phase approach for setting HAP
emission standards. Sierra Club v. EPA,
353 F.3d 976, 980 (DC Cir. 2004). The
first phase is the initial standard setting
phase, which is the phase at issue in
this rulemaking.8 In this phase, the
standards are technology-based, and this
is true regardless of whether we issue
MACT standards under CAA section
112(d)(2) and (d)(3), or GACT standards
under CAA section 112(d)(5).9 See
Senate Report at 148 (1989); Sierra Club
v. EPA, 353 F.3d at 980.
In this final rule, EPA is establishing
emissions standards for this area source
category under CAA section 112(d)(5),
which authorizes EPA to set emissions
standards based on GACT for a listed
area source category. The legislative
history describes GACT as ‘‘methods,
practices, and techniques which are
commercially available and appropriate
for application by sources in the
category considering economic impacts
and the technical capabilities of the
firms to operate and maintain the
emissions control systems.’’ S. Rep. No.
101–228, at 171 (1989) (Senate Report).
Consistent with the statute and the
legislative history, in determining
GACT, we evaluated the control
technologies and management practices
that reduce benzene emissions from the
Gasoline Distribution (Stage I) Area
Source category, and we assessed the
costs of implementing such approaches.
We did not consider health impacts or
8 The second phase of standard setting involves
a risk-based analysis. Specifically, CAA section
112(f)(2) requires EPA to determine—8 years after
issuance of the initial MACT standard—whether
residual risks remain that warrant more stringent
standards than achieved through MACT. CAA
section 112(f)(5) provides that the Agency shall not
be required to conduct a residual risk for area
sources for which EPA has issued a GACT standard.
9 CAA section 112(d)(4) does provide, however,
that with respect to pollutants for which the EPA
Administrator has established a health threshold,
EPA can consider such threshold in setting
standards under CAA section 112(d). Benzene is a
carcinogen and is, thus, not a pollutant for which
the Administrator has established a health
threshold, and, therefore, CAA section 112(d)(4) is
not relevant to this category.
PO 00000
Frm 00010
Fmt 4701
Sfmt 4700
risks in determining GACT for the
facilities in this area source category, as
the commenter recommended, nor were
we required by statute to do so.
However, we note that health risk did
play a role in this process in that the
determination of which pollutants to
regulate and from which categories was
governed by the statutory requirement
to regulate sources accounting for 90
percent or more of the 30 HAP that
present the greatest health threat in
urban areas.
Regarding the comment concerning
whether State and local regulations may
be more stringent than Federal
regulations, we recognize that this could
be an issue in a few States. As an initial
matter, however, for the reasons
described herein, we believe the record
for this final rule fully supports the
GACT determinations that we made for
the affected facilities. A survey
conducted by STAPPA–ALAPCO in
2002 showed that only two States, Idaho
and South Dakota, were precluded from
issuing State regulations more stringent
than Federal rules. Twenty four other
States have similar restrictions but
include a variety of exceptions such as:
(1) Pre-existing rules; (2) when
significant benefits can be achieved; or
(3) when the requirements are needed to
meet State Implementation Plan (SIP)
commitments. We believe that most
States that have elected to implement
standards more stringent than the GACT
standards finalized today for the
gasoline distribution (Stage I) area
source category will be able to justify
maintaining their standards based on
VOC reduction benefits or ozone nonattainment requirements.
B. Selection of Regulatory Alternative
Comment: Two commenters
recommended that if proposed RA 2 or
RA 3 are considered, that the
throughput volume of the GDF storage
tanks be taken into consideration and
explicitly expressed in the regulatory
text. In the commenters’ view, GDF
should be re-defined to address
commercial or commercial-like
operations only. The commenters
further asserted that facilities with
storage tanks between 250 and 2,000
gallons that do not have high volume
throughputs should not be regulated as
the reduction in emissions will not be
significant if the facility is filling the
tanks only once or twice a year. One
commenter stated that, using AP–42
emission factors, a rough estimate of the
cost-effectiveness for a throughput of
1,000 gallons per year over the 15-year
life of the tank is $79,000 dollars per ton
of VOC and $1,100,000 dollars per ton
of HAP.
E:\FR\FM\10JAR2.SGM
10JAR2
yshivers on PROD1PC62 with RULES2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
Two of the commenters stated that if
EPA adopts either proposed RA 2 or RA
3, it would pose unnecessary regulatory
burdens, conflict with most State RACT
requirements, and likely prove to be
ineffective in controlling ozone-causing
vapors. One commenter stated that if
EPA adopts either proposed RA 2 or RA
3, the NESHAP should be limited to
GDF with storage tanks of greater than
1,000 gallons capacity.
One commenter stated that, with very
few exceptions, State/local RACT rules
set tank capacity thresholds much
higher than 250 gallons. In objecting to
proposed RA 2 and 3, the commenters
stated: (1) The 250 gallon NESHAP
applicability threshold under proposed
RA 2 and 3 for GDF is lower than all but
two State RACT regulatory applicability
thresholds; (2) establishing a NESHAP
threshold lower than most RACT
regulations will lead to confusion on the
part of small owners of small tanks who
would be subject to the NESHAP, but
not the RACT requirements in most
urban areas; (3) many manufacturing
facilities operate numerous smallcapacity gasoline dispensing units to
fuel a variety of fire protection,
maintenance, fleet and pool vehicles, as
well as small non-road equipment such
as forklifts, landscaping/mowing
equipment, portable generators, and
portable pumps. The commenter
explained that these fueling operations
should be exempt from the NESHAP
because the proposed rule would
conflict with State and local RACT
requirements under SIP for the ozone
National Ambient Air Quality
Standards, and thus would require
retrofits to the fueling areas.
Response: These commenters raise
several issues related to the application
of the proposed rule to GDF, and
especially to small GDF. First, we
believe that the preamble to the
proposed rule is clear that EPA intended
for the proposed rule to cover both
public and private GDF. The types of
storage tanks found at private refueling
facilities are the same as those found at
large and small retail GDF. Likewise, the
potential for emissions and emission
reductions and the control technology is
the same.
Second, as proposed, the rule
required submerged fill on storage tanks
of greater than 250 gallons capacity.
This threshold level for control was
based on a review of applicable State
and local rules and is believed to be
consistent with existing requirements
that cover a large portion of the country.
For the final rule, we considered the
comments above by analyzing the costs
and cost-effectiveness at these small
tanks. Under CAA section 112(d)(1), we
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
can distinguish among classes, types,
and sizes of sources within a source
category. We have finalized different
requirements for the smallest of storage
tanks because the HAP costeffectiveness of submerged fill climbs
significantly as the throughput of a tank
becomes very small. If you assume a 250
gallon capacity tank is loaded once a
week (1,000 gallons a month), which is
an unusually high number of loadings,
the resulting cost-effectiveness for
submerged fill would be well above
$36,000 per ton of HAP reduced. Using
the threshold in many State VOC rules
for vapor balancing (10,000 gallons per
month) the cost-effectiveness is $12,000
per ton of HAP reduced. Therefore, we
agree with the commenters’ concern and
the final rule distinguishes between
GDF based on the monthly throughput
of the facility. Specifically, we are
adopting a facility-wide threshold that
distinguishes between GDF with a
monthly throughput of 10,000 gallons
per month or more and those below this
threshold. In addition, we are retaining
from the proposal that submerged fill is
not required for individual tanks with a
250-gallon capacity independent of
monthly throughput. However, under
the final rule, all GDF, including those
with throughput less than 10,000
gallons per month and tanks with a 250gallon capacity or less, are required to
perform the management practices to
minimize evaporation.
The submerged fill and management
practices requirements reduce
nationally 150 tons of HAP annually,
including 5 tons of benzene emissions.
The cost of both the submerged fill for
larger GDF and management practices
for all GDF is a capital cost of $3 million
nationally, but an annual cost credit of
almost $500,000 nationally because the
value of the recovered gasoline ($1.73
million) is higher than the annual
control costs ($1.26 million). In addition
to establishing these monthly
throughput levels, we have maintained
the reduced requirements for
notifications, reporting, and
recordkeeping that were proposed for
GDF.
Comment: Many commenters
expressed their preference for proposed
RA 3 and several offered
recommendations on variations of the
Stage I vapor balancing requirements for
GDF. One commenter suggested an
annual throughput threshold of 200,000
gallons for Stage I vapor balancing
applicability. The commenter further
suggested that this applicability
threshold should be on a calendar year
basis with onsite records of monthly
throughput required for all GDF, even
those below the 200,000 gallon
PO 00000
Frm 00011
Fmt 4701
Sfmt 4700
1925
threshold. Two commenters stated that
any requirement for Stage I vapor
balancing should specify that, unless
otherwise approved by the air pollution
control agency having jurisdiction, only
California Air Resources Board (CARB)
certified Stage I vapor balancing
equipment should be allowed at GDF.
One commenter recommended that
Stage I vapor balancing be universally
required within 2 years of adoption of
40 CFR part 63, subpart BBBBBB for
tanks above a specified size and
throughput and that all new GDF
storage tanks and all new delivery
trucks be equipped with Stage I vapor
balancing equipment. Another
commenter believes that all GDF (urban
and rural) with throughputs greater than
10,000 gallons per month should be
required to install and operate a vapor
balance system.
Two other commenters expressed
opposition to proposed RA 3 and stated
that they believe that vapor balancing is
not cost-effective and is substantially
more difficult to implement than
submerged fill. The commenters claim
that proposed RA 3 would impose
significant costs on GDF to achieve only
marginal gains over submerged filling.
Two additional commenters stated
that proposed RA 3 would cover a high
percentage of above-ground tanks that
are not easily retrofitted with Stage I
vapor recovery. Specifically, the
commenter stated that retrofitting small
above-ground tanks with vapor recovery
poses two practical difficulties. First,
most small above-ground tanks were not
designed with fittings that will
accommodate a vapor recovery line.
According to the commenter, for these
tanks, vapor recovery retrofit would
require either cutting and welding to
install new fittings or tank replacement.
Second, because the fittings in aboveground tanks are elevated above grade,
any fuel that enters the vapor recovery
line does not drain readily. The
commenter noted that this would cause
vapor blockage and ineffective vapor
recovery. The commenter further
indicated that many States do not
approve vapor recovery systems for any
above-ground tanks for this reason.
Response: After considering all of the
comments, we have concluded that GDF
vapor balancing at GDF is cost-effective
and should be required for GDF with
throughputs greater than or equal to
100,000 gallons per month. We have not
made any significant changes since the
proposal on how we implement the
vapor balancing requirements. Also, we
believe our unit costs are representative
of the installed control costs.
As indicated by the proposal
preamble and several commenters,
E:\FR\FM\10JAR2.SGM
10JAR2
1926
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
specified in the final rules, that their
system is capable of reducing emissions
from the loading of their storage tanks
by 95 percent. We also allow owners or
operators to demonstrate compliance
with the requirements of the final rule
by informing EPA that the facility has
installed CARB or other State certified
vapor balance systems. We do not,
however, require that only CARB
certified systems be allowed as
suggested by the commenter. This
approach of allowing owners or
operators to demonstrate that their
chosen vapor balance systems are
effective is used by many State and local
agencies and we believe that the added
flexibility is beneficial, and, therefore,
have not made implementation changes
to what was proposed.
We believe that vapor balancing is
GACT for these GDF. The technology of
vapor balancing has been effectively
applied to storage tanks at bulk plants
(nearly all having above-ground tanks)
and GDF for many years. The
commenter who claimed that vapor
balancing would be difficult or costly
for many facilities, especially those with
above-ground tanks, did not provide any
supporting data or cost estimates, and
we do not have any information that
supports these claims. Our analysis of
the cost of installing a vapor balance
system was based on an average cost
that included about $2,000 in labor
costs plus $2,500 in capital costs, based
on estimates obtained from the States of
California and Texas. While it is
possible that some facilities may incur
costs greater than these, we believe that
they represent the upper end of the
range of ‘‘typical’’ costs for installing a
vapor balance system. In fact, one State
agency submitted a vendor’s cost
estimate of $1,044 plus labor for a
submerged fill and vapor balance
system. Thus, we believe that not only
is vapor balance technology available,
but that the cost we analyzed is a
reasonable estimate.
yshivers on PROD1PC62 with RULES2
vapor balancing is required by many
State and local agencies and is,
therefore, already generally available
and in widespread use. About 62
percent of the national volume of
gasoline is vapor balanced at GDF. 10
Given that most of these vapor balance
systems were installed to control VOC
instead of HAP (nearly 100 percent of
gasoline vapor versus about 5 percent,
respectively), we analyzed the HAP
emissions reduction and costs for
different sized GDF. We concluded that
a monthly throughput could be
developed to reasonably estimate the
size of the GDF, thereby enabling us to
better determine what is GACT for the
different sizes of GDF. In our evaluation,
some emission and cost parameters
changed (HAP content and interest rate,
see section VI of this preamble). We
concluded from our cost and emission
reduction analysis that when vapor
balancing is applied to facilities with
throughput levels above 100,000 gallons
per month, the HAP cost-effectiveness is
about $3,700 per ton of HAP reduced as
opposed to the cost-effectiveness of the
10,000 gallon per month threshold
analyzed at proposal (about $9,000 per
ton). The national emission reductions
and costs just for vapor balancing are
about 2,600 tons of HAP reduced, at a
capital cost of $44 million and an
annualized cost of $9.3 million per year.
In total, for all bulk facilities and all
GDF requirements, the total national
impacts of today’s final rules are 4,900
tons of HAP reduced, at a capital cost
of $75 million. The annualized capital,
operating and maintenance, and
compliance costs are $20 million;
however, there is a $26.5 million per
year credit for the recovered gasoline,
resulting in a total annualized cost
credit of $6.5 million per year for these
final rules.
As described in the proposal
preamble (71 FR 66073, November 9,
2006), we evaluated various vapor
balancing requirements and selected an
implementation approach for the
proposed and final rules that included
management practices rather than
requiring each owner or operator to test
the efficiency of installed vapor balance
systems. We also proposed, and
included in the final rules, that owners
or operators may use other equipment
configurations if they successfully
demonstrate to the Administrator
through performance testing, as
Comment: Two commenters stated
that EPA should modify the rule to
allow for facilities to comply with either
NSPS subpart Kb 11 of 40 CFR part 60
or NESHAP subpart WW 12 of 40 CFR
part 63 for both internal and external
10 As reported at proposal, vapor balancing is
already used at GDF in areas where about 68
percent of the gasoline is consumed. However,
some smaller facilities are exempted from this
requirement, thus, about 62 percent of the gasoline
delivered to GDF is actually controlled with vapor
balancing.
11 40 CFR part 60, subpart Kb, Standards of
Performance for Volatile Organic Liquid Storage
Vessels (Storage Vessels New Source Performance
Standards (NSPS)).
12 40 CFR part 63, subpart WW, National
Emission Standards for Storage Vessels (Tanks)—
Control Level 2.
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
C. Bulk Terminals
1. Alternative To Comply With 40 CFR
Part 63, Subpart WW
PO 00000
Frm 00012
Fmt 4701
Sfmt 4700
floating roof tanks. In addition, the
commenters stated that the rule
language and Table 2 should be revised
to allow for compliance with subpart
WW in lieu of subpart Kb for those
tanks subject to subpart Kb and to
provide facilities the option to switch
from subpart Kb to subpart WW. The
commenters also suggested that the
regulation should be clarified to reflect
that a facility may choose to comply
with subpart WW in lieu of subpart Kb
for tanks subject to controls only under
the proposed area source rule (with
deck fitting controls waived if the tank
is subject to controls only under the area
source rule). The commenters explained
that the ability to comply with either
rule is important because subpart WW
provides clarity in areas where subpart
Kb is unclear. The commenters stated
that these clarifications are particularly
important with respect to ladder/
guidepole combinations on internal
floating roof tanks. According to the
commenters, these devices are
commonly used with internal floating
roof tanks, yet were not addressed in
prior rulemakings. The commenters
claim that while subpart WW allows for
an equivalency demonstration on the
basis of emission factors and specifies
test methods for determining emission
factors, subpart Kb is unclear on
equivalency demonstration.
Response: The final rule for these
storage tanks was based on portions of
40 CFR part 60, subpart Kb, which
applies to storage tanks installed after
1984. EPA determined that these
requirements are GACT for the storage
tanks in this area source category and
have, therefore, included them in the
final rule. Alternatively, the final rule
allows affected facilities the option of
complying with applicable provisions in
40 CFR part 63, subpart WW, as EPA
believes these requirements are
equivalent to the applicable provisions
in subpart Kb. See Table 1 in 40 CFR
part 63, subpart BBBBBB for the specific
requirements from these subparts that
storage tanks at bulk facilities must
implement as GACT under this area
source rule.
Additionally, recognizing that certain
facilities may be simultaneously subject
to 40 CFR part 60, subpart Kb and this
area source rule, the final rule specifies
that owners or operators of facilities that
are subject to both subparts, and who
are currently operating in compliance
with all applicable requirements in
subpart Kb, will be deemed in
compliance with this area source rule.
However, we are not incorporating the
commenter’s recommendation that
facilities subject to subpart Kb should
instead be allowed to comply with 40
E:\FR\FM\10JAR2.SGM
10JAR2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
yshivers on PROD1PC62 with RULES2
CFR part 63, subpart WW. We do not
have the authority to allow owners or
operators subject to standards under
different CAA provisions (section 111
and section 112) to choose which
regulations will apply to their facilities.
Facilities must comply with all
applicable regulations.
In addition, we disagree with the
commenters claim that the requirements
of 40 CFR part 60, subpart Kb are
unclear. We believe, and industry
agreed in the Storage Tank Emission
Reduction Partnership Program
agreement (65 FR 19891, April 13,
2000), that the subpart Kb wording of
‘‘no visible gap’’ means that the slotted
guidepoles are required to be controlled.
2. Control of Guidepoles
Comment: One commenter
recommended that the final rule require
that rim seals and guidepoles be
controlled on all external floating roof
tanks (EFRT) and that no other deck
fitting controls be required. The
commenter presented emissions and
emissions reduction estimates that they
believe supports their position that
EFRT guidepoles are the primary source
of deck fitting emissions. In their
example case of a tank equipped with a
slotted guidepole, 99 percent of the
potential emission reductions from the
control of deck fittings are attributable
to control of the slotted guidepole. The
commenter also presented information
to support their conclusion that the
control of guidepoles is a cost-effective
measure, whereas the control of other
deck fittings is not cost-effective.
Response: We evaluated the
commenter’s recommendation, and the
supporting materials they provided, and
decided not to revise the final rule as
requested. We believe that the
commenter is correct that guidepoles are
the largest single source of emissions
from deck fittings, based on typical
emission factors presented by the
commenter, and that controls are
available and required by many rules.
Thus, we agree that they should be
controlled under this rule. We also agree
that, in most typical cases, the
emissions from all other deck fittings
are lower. However, we do not agree
that all of the other deck fittings should
be allowed to remain uncontrolled.
The primary reason for our position
on the control of deck fittings is the
difficulty in determining the point at
which an ‘‘opening’’ in the deck
becomes large enough to be a serious
concern. For example, a loose-fitting
cover on an access hatch may not be a
significant source of emissions if the
openings or gaps around the cover are
small. However, if the same cover had
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
a gap twice as large, the emissions
would be much greater and would
probably warrant controls. The process
of determining when a gap around a
cover actually becomes equivalent to an
opening in the deck would be very
difficult, not only for facility personnel,
but also for enforcement personnel.
Another factor that we considered in
making the decision to require deck
fitting controls is the variable nature of
the emissions from EFRT. While the
emission factors used to estimate
emissions from EFRT are believed to
provide reliable estimates for the typical
tank, there may be case-by-case factors
that have a significant impact on
emissions. For example, the relative
locations of two or more gaps or
openings in the deck may lead to the
‘‘channeling’’ of air currents that
significantly increase the emission rate.
The position of a gap or opening relative
to the prevailing wind direction
(whether the opening is normally
shielded or exposed) may also influence
the emission rate.
As mentioned earlier, and for the
reasons discussed above, we believe that
the final rule should require control of
all deck fittings. Because the cost of
installing fitting controls on all deck
fittings is low, and, as proposed, we are
allowing up to 10 years for the
installation of these controls so that the
fittings can be installed at a time when
the tank is out of service and
appropriate service staff are on site, we
believe that this requirement is
reasonable.
D. Testing and Monitoring
1. Continuous Monitoring and CEMS on
Vapor Processors
Comment: One commenter
recommended that EPA consider
allowing Continuous Parameter
Monitoring Systems in cases where the
facility owner or operator can
demonstrate that the monitored
parameter is sufficient to ensure
compliance with the standards. The
commenter stated that parameter
monitoring is already in place at most,
if not all, of these facilities in their
State. Several other commenters support
alternative monitoring options for vapor
combustion and carbon adsorption
units. The commenters claim that these
alternatives, coupled with
comprehensive annual inspections and
adequate maintenance programs and the
more frequent compliance testing
requirements in the proposal, should be
reasonable to assure compliance with
the proposed emission limits. The
commenters provided emissions testing
data to support their claims that the
PO 00000
Frm 00013
Fmt 4701
Sfmt 4700
1927
alternative monitoring options were an
effective means of ensuring continuing
compliance. They also provided specific
recommendations on inspection and
maintenance requirements that they
believe should be included in the
alternative monitoring option.
Response: We have reviewed the data
provided by the commenters and
believe that the alternative monitoring
options will be acceptable for ensuring
compliance with the final rule. The
devices used to control gasoline vapors
emitted from loading racks at bulk
terminals are almost exclusively thermal
systems or carbon adsorbers. Thermal
systems achieve very high removal
efficiencies in this source category
because the vapor stream being
controlled is extremely combustible.
The data provided by the commenters
show that as long as a pilot flame is
present to ignite the vapors, these
systems consistently achieve controlled
emission levels far below the level
required by the final rule. The
performance of carbon adsorbers has,
likewise, been shown by the
commenter’s data to remain sufficiently
high when the system vacuum levels are
maintained at the appropriate levels.
The commenters also recommended
that numerous specific components of
the control systems be inspected
periodically (daily, for most items) and
maintained as necessary as a means of
assuring that the devices continue to
perform as designed. Most of the
commenter’s recommendations have
been incorporated into the final rule.
The commenters did, however,
recommend that the daily inspections
occur during each ‘‘manned day of
operation.’’ We did not limit the
inspections to manned days of
operation, but require them for each day
of operation. We believe that at least the
routine daily inspections should be
conducted during each day that the
facility is in operation, regardless of
whether the facility has operators on
site, to assure continuous compliance.
For those facilities with no on-site
personnel, the owner or operator can
choose not to use this alternative
monitoring approach, they can choose
to have someone visit the site daily, or
they can install monitoring equipment
necessary to record the specified
parameters on a daily basis.
The proposed rule specified in 40
CFR 63.11092(d) that operation of the
vapor processing system in a manner
exceeding or going below the monitored
operating parameter value constituted a
violation of the emission standard for
the applicable loading rack. As with the
major source MACT standard for this
source category, we continue to require
E:\FR\FM\10JAR2.SGM
10JAR2
yshivers on PROD1PC62 with RULES2
1928
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
that operation of the system at times
when specific monitored parameters
exceed or go below the applicable
monitored parameter value be reported
as a violation of the emission standard.
However, we did consider what the
continuous compliance status should be
if the additional (to parameter
monitoring) periodic maintenance and
inspection procedures reveal
operational problems. The commenters
stated that problems discovered during
maintenance and inspections should
trigger corrective actions, but should not
be considered violations of the emission
standard. Because we have no data to
support a direct relationship between
the maintenance and inspection
procedures and the actual emission
rates, we agree with the commenters
and believe that the results of these
procedures should be viewed as
indicators of proper operation rather
than violations of the emission
standard.
To ensure that proper maintenance
and inspection procedures are followed,
we have included in the final rule a
requirement that owners or operators
prepare a monitoring and inspection
plan. The plan must contain a
description of each item to be included
in the periodic inspections and must
define the normal operation of each
item. The plan must also specify
conditions that would be considered
malfunctions, describe the corrective
actions to be taken to correct any
malfunction, and define what the owner
or operator considers to be a timely
repair for each potential malfunction.
For the timing of necessary corrective
actions, we have used the corrective
action timing from the recently
proposed NESHAP for Iron and Steel
Foundries (72 FR 52984, September 17,
2007). We are requiring that facilities
initiate corrective action to determine
the cause of a problem within 1 hour,
initiate corrective action to fix the
problem within 24 hours, and complete
all corrective actions to fix the problem
as soon as practicable (and as specified
in the monitoring and inspection plan).
Thus, problems discovered during
inspections will be monitored and
recorded by being subject to corrective
actions according to a monitoring and
inspection plan that the owner or
operator is required to develop. Owners
or operators will be required to maintain
a record of all corrective actions and
report them semi-annually.
We believe that, when combined with
the periodic maintenance and
inspection requirements, the monitoring
for the presence of a flame in a thermal
system and vacuum level in a carbon
adsorber will provide adequate
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
assurance of continuing compliance
with the final rule. We have, therefore,
incorporated the commenter’s
recommended options for alternative
parameter monitoring and periodic
inspections (and associated corrective
action) into the final rule.
2. Past Performance Tests
Comment: One commenter supports
EPA’s willingness to accept past
performance tests, but requests that
performance tests completed within the
5 previous years be accepted. Many
States require permit updates on a 5year cycle, so some facilities may have
performance tests only every 5 years.
Response: When we proposed to
accept performance tests conducted
within the past 3 years, we considered
that time period to be representative of
typical permit cycles. After
consideration of the commenter’s
request, we agree with the commenter
that 5 years is a more typical permit
cycle and we have revised the provision
in the final rule to more accurately
correspond to the typical 5-year cycle
for most State permits. In the final rule,
we specify that we will accept
performance testing completed up to 5
years prior to submittal under 40 CFR
63.11092 rather than the 3 years that
was proposed.
E. Control Costs and Cost Analyses
Performed
1. Loading Racks
Comment: Two commenters stated
that the costs of installing control
devices at loading racks is significantly
more than was estimated in EPA’s cost
analysis of the 80 mg/l control level.
One of the commenters stated that there
were currently about 20 small
uncontrolled loading racks in use and
submitted estimates of the costs to
convert these uncontrolled loading
racks to bottom loading and to add a
vapor processor system. The commenter
also stated that the HAP costeffectiveness for converting these
uncontrolled loading racks was very
poor and suggested that a throughput
threshold of 2 million barrels per year
was justified based on HAP costeffectiveness. Three commenters
support the requirement of submerged
fill for ‘‘small’’ bulk gasoline terminals
rather than routing vapors from the
loading rack to a vapor control device.
The commenters claim that this level of
control is appropriate because these
smaller facilities are typically located in
rural areas as designated by the
urbanized area plus offset and urban
cluster definition (40 CFR 63.761), and,
as such, do not pose an unacceptable
PO 00000
Frm 00014
Fmt 4701
Sfmt 4700
health risk to urban areas. One of these
commenters also presented data and
concluded that the cost and costeffectiveness of converting uncontrolled
splash loading facilities to submerged,
top-loading facilities was very
reasonable.
Response: In the proposed rule, all
bulk terminals would have been
required to control loading rack
emissions to 80 mg/l, or less, with a
vapor processor. We reviewed both the
cost data provided by the commenter
and the data we used to develop the
proposal and then considered the
appropriateness of establishing a daily
throughput for bulk terminals in the
final rule. We have placed a
memorandum documenting our analysis
in the docket (Docket No. EPA–HQ–
OAR–2006–0406).
Based on our review of the
information provided by the
commenter, and our analysis of their
recommendation to include a daily
throughput for bulk terminals required
to meet the 80 mg/l loading rack
standard, we have decided to revise the
final rule. Because of the large capital
investment required for installing these
controls (over $3 million per facility),
the resulting HAP cost-effectiveness is
greater than $10,000 per ton for facilities
with a gasoline throughput of less than
250,000 gallons per day. We are,
therefore, including in the final rule a
different requirement for those
terminals with an average gasoline
throughput less than 250,000 gallons
per day (about 2 million barrels per
year).
Specifically, we determined that
GACT for these low throughput
facilities is submerged fill systems for
outgoing loads. We believe that both the
initial capital investment and the HAP
cost-effectiveness of this requirement
are reasonable. The capital investment
is about $25,000 per facility and the
annualized cost of the capital
investment is about $2,400. However,
because the value of the recovered
product is about $75,700 per year, the
net annualized cost of control is a credit
of about $73,000 per year. The resulting
HAP cost-effectiveness is a credit of
almost $11,000 per ton. The
requirement to use submerged fill will
result in greater than 50 percent
reduction in emissions compared to the
splash fill base case. The impacts of
controls on bulk terminals (submerged
fill for terminals below 250,000 gallons
per day throughput, 80 mg/l vapor
processors terminals above 250,000
gallons per day, and leak testing of
vapor recovery tank trucks loaded at
terminal) in the final rule is a reduction
of 190 tons of HAP per year at a capital
E:\FR\FM\10JAR2.SGM
10JAR2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
cost of $500,000 and a cost credit of $1.4
million in annualized cost (because of
the value of the gasoline vapor
recovered (about $1.5 million)).
Although the commenters claim that
these sources are located in rural areas,
the decision to include this level of
control for small bulk terminals was
based on our re-analysis of the costs of
control rather than on location. As was
discussed in the response to an earlier
comment, we believe that the
development of area source standards
that apply nationwide in all areas is
appropriate given the facts and
circumstances of this particular source
category.
yshivers on PROD1PC62 with RULES2
2. Internal Floating Roof Tanks
Comment: One commenter submitted
facility data used to develop estimates
of the cost, HAP reductions, and HAP
cost-effectiveness of adding a secondary
seal to internal floating roof tanks (IFRT)
that have vapor mounted primary seals.
The commenter provided capacity and
throughput data for nine storage tanks.
The commenter did not provide any
specific recommendations for changes
to the proposed rule, but stated that the
cost-effectiveness for this control
measure was very poor.
Response: As a result of our review of
the data provided by the commenter,
and a re-evaluation of the costs we
estimated during the development of the
proposal, we have decided to revise the
final rule. In our examination of the
impacts of storage tank controls prior to
proposal, we combined the estimated
impacts for IFRT and EFRT and
considered the combined impacts. The
impacts of the proposed rule, when all
storage tank types are combined, were
considered to be reasonable. However,
the commenter is correct that the costeffectiveness of adding secondary rim
seals to an IFRT with an existing vapor
mounted primary rim seal, when
considered separately from the other
tank types, is estimated to be greater
than $150,000 per ton of HAP reduced.
The final rule will, therefore, require
that IFRT have a primary seal but will
not require a secondary seal.
F. Notifications, Reporting, and
Recordkeeping
Comment: One commenter supported
the proposal to waive the requirements
for submission of Initial Notification
and Notification of Compliance Status
for bulk plants and GDF and suggests
this waiver be expanded to include
pipeline breakout stations and pipeline
pumping stations.
The commenter also suggests that all
facilities be allowed to submit reports
only when there are deviations to report
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
rather than being required to submit
semi-annual reports even if there are no
deviations during the period. The
commenter stated that if there were no
deviations, there would be no report.
The commenter noted that EPA wrote in
the preamble to the proposed rule
‘‘there are approximately 1,800 pipeline
breakout stations nationwide.’’ The
commenter points out that this would
result in 3,600 new semi-annual reports
to agencies each year, placing undue
burden on facilities and agencies. The
commenter suggested that, as an
alternative, only terminals and bulk
plants should be required to submit
semi-annual reports. The commenter
stated that the regulatory requirements
proposed for pipeline breakout stations,
pipeline pumping stations, and GDF are
easily auditable (e.g., log of equipment
leak inspections, installation of
submerged fill) and should not require
semi-annual reporting. The commenter
also stated that EPA should clarify that
delay of repair is allowed with proper
documentation and that the
Administrator’s approval is not
required.
Response: Our intent in not requiring
the submission of Initial Notification
and Notification of Compliance Status
for bulk plants and GDF was to reduce
the burden on small businesses. We also
believe this provision is appropriate
because of the relative ease with which
an inspector can determine if these
facilities are meeting either submerged
fill or vapor balancing requirements of
the rule. However, it is more difficult to
determine compliance with the storage
tank requirements and equipment leak
inspection requirements for pipeline
breakout stations and pipeline pumping
stations. We believe that it is reasonable
to require these larger facilities to
submit notifications certifying their
status. These facilities are also typically
not small businesses, the commenter
did not provide data to support their
position, and the reporting burden is not
expected to be a significant burden.
With regard to the commenter’s
position that only reports of deviations
be required rather than semi-annual
reporting, we agree that for some source
types these reports may not be
necessary. Thus, we have revised the
periodic reporting requirements in the
final rule to require that pipeline
pumping stations and bulk plants must
only submit, on a semi-annual basis,
any occurrences of an equipment leak
for which no repair attempt was made
within 5 days or for which repair was
not completed within 15 days after
detection. If there are no such
occurrences, no semi-annual report is
required. However, the monthly
PO 00000
Frm 00015
Fmt 4701
Sfmt 4700
1929
equipment leak inspections must be
performed and a record of the
inspections must be kept. We have
made this revision because, other than
monthly equipment leak inspections,
the only control measure typically
required at these facilities is the use of
submerged fill at bulk plants. Because
submerged fill equipment is not
expected to deteriorate significantly
over time and is not subject to operating
variables that impact emissions, we do
not believe that semi-annual reporting is
necessary. Likewise, as the commenter
pointed out, the monthly equipment
leak requirements include the
maintenance (recording of the
inspection event) of an inspection log
which is required to be readily
accessible to an inspector. We also
considered that there are a large number
of these facilities and that a significant
number of the semi-annual reports
would only be reporting that no delays
in repair occurred. Therefore, as long as
the equipment leak inspections are
performed and documented, and as long
as there are no delays in needed repairs,
we do not believe that any reporting is
necessary.
We have not, however, changed the
requirement for semi-annual reporting
by bulk terminals and pipeline breakout
stations because we view these reports
as necessary to ensure that facilities
operate and maintain their storage tanks
(and loading racks at bulk terminals)
according to the provisions of the rule.
Finally, in response to the
commenter’s suggestion, we have
clarified in the final rule that
Administrator approval is not necessary
for a facility to utilize the delay of repair
provisions in the rule. Instead, the
facility must document why repair
within 15 days was not feasible, and
provide that explanation in its next
semi-annual report. We would point
out, however, that this requirement may
be implemented by a delegated
authority under 40 CFR 63.11099 and
that the reasons for a delay in repairs
must be properly documented and must
be acceptable to the delegated authority.
If the documentation is not acceptable
to the delegated authority, the delay in
repair may be considered a violation of
the standards.
VI. Summary of Environmental, Energy,
Cost, and Economic Impacts
As discussed earlier, gasoline
distribution activities are carried out at
several different types of facilities.
These include bulk terminals, pipeline
breakout stations, pipeline pumping
stations, bulk plants, and GDF. Our
analysis of the gasoline distribution
industry led us to estimate that there
E:\FR\FM\10JAR2.SGM
10JAR2
1930
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
yshivers on PROD1PC62 with RULES2
were approximately the following
numbers of affected area sources
incurring costs (and emission
reductions) within each type of facility:
20 bulk terminals, 1,600 cargo tanks,
400 pipeline breakout stations, 1,800
pipeline pumping stations, 390 bulk
plants, and 9,900 GDF. The following
paragraphs present our estimates of the
impacts that these final rules would
have on these facilities.
A. What are the air impacts?
Nationwide, gasoline distribution
facilities emit annually an estimated
475,000 tons of VOC and 22,800 tons of
HAP (including 800 tons of benzene).
As discussed earlier, gasoline no longer
contains EDC so there are no longer any
emissions of EDC from this source
category. We estimate that, after the
final rules are implemented, annual
HAP emissions will be reduced by 4,900
tons, which includes 175 tons of
benzene, from about 14,000 facilities.
The final rules will also reduce VOC
emissions by 103,000 tons per year,
which represents about a 22 percent
reduction in emissions of these
pollutants, compared to the baseline. At
proposal, we did a separate analysis of
the impacts of the proposed Mobile
Source Air Toxics Rule (MSAT), but
since the MSAT rule is now final, it is
considered as part of the baseline.
Instead of the total HAP content of
gasoline vapor, including 0.27 percent
benzene (as used in our analysis at
proposal), the MSAT rule will reduce it
to about 0.17 percent. Also, we assume
that MTBE will be completely phased
out of the gasoline pool. The net effect
is that the HAP content will be reduced
from about 7.3 percent (estimated at
proposal) to about 4.8 percent in
gasoline vapor. Thus, all impact
estimates reported in this notice reflect
the impacts after full implementation of
the MSAT rule and the elimination of
MTBE in gasoline.
We project that any adverse air
impacts associated with this rule will be
insignificant. Using national data from
all stationary benzene emission sources
in the 1999 National Air Toxic
Assessment (NATA) and ratioing them
to the national benzene emissions from
this source category, we approximate
that this rule will reduce about 22
percent of the current benzene
emissions from these sources, resulting
in a reduction of incidences of cancer
from benzene exposure by 0.08 cases
per year. These cancer incidence
reduction approximations are
considered a very rough estimate
because no exposure analysis was
performed for this source category and
the 1999 NATA data should be used
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
cautiously, as the overall quality and
uncertainties of the NATA results will
vary from location to location, as well
as from pollutant to pollutant. In
addition, EPA’s Scientific Advisory
Board has cautioned the Agency against
using the results of the NATA
assessment for regulatory purposes.
Further information on the limitations
of NATA is discussed at the following
Web site: https://www.epa.gov/ttn/atw/
nata1999/.
B. What are the cost impacts?
The cost of implementing the final
rules for gasoline distribution area
source facilities would include the
capital and annualized costs to control
storage tanks, loading racks, equipment
leaks, and cargo tanks, as well as the
costs of complying with the testing,
monitoring, reporting, and
recordkeeping requirements. Since
proposal we changed the interest rate
used in our cost analysis to amortize the
initial costs. The annualized cost
estimates presented in the proposal are
based on a 10 percent interest rate. As
we reported in the proposed rule, cost
documentation, the interest rate that the
Agency uses for cost analyses such as
these should have been 7 percent. We
committed to correct that over-estimate
in the final analyses. We have also
corrected the cost analysis to
incorporate the changes discussed in
section III of this preamble and to
incorporate the simplified monitoring,
reporting, and recordkeeping
requirement costs discussed in the
proposal cost documentation. Thus, the
cost analyses reported below and
elsewhere in this notice includes these
changes.
The final rules are estimated to result
in capital expenditures of
approximately $75 million. The
annualized cost of the capital
expenditures is estimated to be about
$7.5 million. Annual operating and
maintenance costs are estimated at
about $4.1 million. We have estimated
the annual costs of testing, monitoring,
reporting, and recordkeeping to be about
$8.4 million. Because of the value ($26.5
million) of the product that is either
recovered or prevented from
evaporating, however, we estimate that
the annualized cost of the final rules is
a credit of about $6.5 million.
C. What are the economic impacts?
These final rules affect area sources
from pipeline transportation, bulk
stations and terminals, local and longhaul trucking, and gasoline stations
which make up the gasoline distribution
industry. We performed an economic
impact analysis with methodology
PO 00000
Frm 00016
Fmt 4701
Sfmt 4700
based on a single-market partialequilibrium analysis of the national
gasoline market. The analysis estimates
changes in gasoline prices and outputs
for affected sources under the control
requirements in the final rules. The
results of our analyses are stated below.
The compliance cost results in an
insignificant increase in gasoline prices.
This price increase is less than 1 cent
per gallon (less than 0.001 percent).
Given these small increase in prices,
the corresponding reductions in
gasoline consumption are also minor.
The estimated annual reduction is less
than 3 million gallons per year.
The overall total annual surplus
changes (social costs/gains), which
reflect changes in consumer and
producer behavior in response to the
compliance costs of the final rule, is a
net gain of $6.5 million.
For more information, please refer to
the Economic Impact Analysis report
that is in the public docket for these
rules.
D. What are the non-air environmental
and energy impacts?
Water quality would not be affected
by implementation of these rules. These
final rules do not contain any
requirements related to water discharges
or wastewater collection, and no
additional gasoline is expected to enter
these areas as a result of these rules. We
project that the implementation of the
required management practices will
result in a decrease in the release of
gasoline to the environment, but we
have not quantified this reduction.
We also project that there will be no
significant solid waste impact. Neither
thermal oxidizers nor condensers
generate any solid waste as a by-product
of their operation. When carbon
adsorption systems are used, the spent
activated carbon that cannot be further
regenerated may be disposed of in a
landfill, which would contribute a small
amount of solid waste.
The control devices used to control
emissions from loading racks and some
storage tanks use electric motor-driven
blowers, dampers, or pumps, depending
on the type of system, in addition to
electronic control and monitoring
systems. The installation of these
devices would have a small negative
energy impact. We believe, however,
that there will be very few, if any, new
installations of these control devices as
a result of these rules. Also, because the
liquid being controlled by these systems
is gasoline, and some of the applied
control measures would keep this fuel
in the distribution system, they would
have a positive impact on this form of
energy. We estimate that these rules
E:\FR\FM\10JAR2.SGM
10JAR2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
would prevent a total of approximately
35 million gallons of gasoline from
being lost to evaporation annually.
VII. Statutory and Executive Order
Reviews
A. Executive Order 12866: Regulatory
Planning and Review
Under Executive Order 12866 (58 FR
51735, October 4, 1993), this action is a
‘‘significant regulatory action.’’ The
Executive Order defines ‘‘significant
regulatory action’’ as one that is likely
to result in a rule that may ‘‘raise novel
legal or policy issues arising out of legal
mandates, the President’s priorities, or
the principles set forth in the Executive
Order.’’ Accordingly, EPA submitted
this action to the Office of Management
and Budget (OMB) for review under
Executive Order 12866 and any changes
made in response to OMB
recommendations have been
documented in the docket for this
action.
yshivers on PROD1PC62 with RULES2
B. Paperwork Reduction Act
The information collection
requirements in these final rules have
been submitted for approval to OMB
under the Paperwork Reduction Act, 44
U.S.C. 3501, et seq. An Information
Collection Request (ICR) document has
been prepared by EPA and has been
assigned EPA ICR number 2237.02. A
copy may be obtained from Susan Auby,
Collection Strategies Division (2822T),
EPA, 1200 Pennsylvania Avenue, NW,
Washington, DC 20460, or by calling
(202) 566–1672. A copy may also be
downloaded from the public docket for
this action (Docket ID number EPA–
HQ–OAR–2006–0406), which can be
found in https://www.regulations.gov.
The information collection requirements
are not enforceable until OMB approves
them.
The information to be collected for
the final area source rules are based on
notification, recordkeeping, and
reporting requirements in the NESHAP
General Provisions in 40 CFR part 63,
subpart A, which are mandatory for all
operators subject to national emission
standards. These recordkeeping and
reporting requirements are specifically
authorized by section 114 of the CAA
(42 U.S.C. 7414). All information
submitted to the EPA pursuant to the
recordkeeping and reporting
requirements for which a claim of
confidentiality is made is safeguarded
according to EPA policies set forth in 40
CFR part 2, subpart B.
These final rules require performance
testing of control devices used to control
emissions from loading racks at bulk
terminals and from some storage tanks
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
at bulk terminals and pipeline breakout
stations. They also require annual
inspections of storage tanks at bulk
terminals and pipeline breakout stations
and collection of cargo tank vapor
tightness documentation by bulk
terminals. In addition, the rules require
periodic pressure testing of vapor
balance equipment at GDF. Finally,
monthly equipment leak inspections at
bulk terminals, pipeline breakout
stations, pipeline pumping stations, and
bulk plants are required. These final
rules do not require any notifications or
reports beyond those required by the
General Provisions. The recordkeeping
requirements require only the specific
information needed to determine
compliance. We have taken steps to
minimize the reporting and
recordkeeping requirements for the
smaller facilities (bulk plants and GDF)
that are affected by these final rules.
The annual monitoring, reporting, and
recordkeeping burden to affected
sources for this collection (averaged
over the first three years after the
effective date of the promulgated rule) is
estimated to be about 129,700 labor
hours per year, with a total annual cost
of $8.4 million per year. Most of this
burden will be spread over
approximately 14,000 facilities that will
be required to keep records and file
reports. Of this total burden, however,
about 68,500 labor hours (and $4.5
million) will be incurred by about 4,200
of the larger, bulk distribution facilities.
Depending on the facility type, these
estimates include two one-time
notifications, a one-time performance
test and report for control devices,
periodic equipment inspections, and
semi-annual compliance reporting. We
did not receive any comments on the
proposed ICR, therefore, the ICR has
only been updated to reflect any
changes in affected sources and
reporting and recordkeeping discussed
earlier in this notice. 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 Federal agency.
This includes the time needed to review
instructions as well as the time to
develop, acquire, install, and use
technology and systems for the purposes
of collecting, validating, and verifying
information, processing and
maintaining information, and disclosing
and providing information; adjust the
existing ways to comply with any
previously applicable instructions and
requirements; train personnel to be able
to respond to a collection of
information; search data sources;
complete and review the collection of
PO 00000
Frm 00017
Fmt 4701
Sfmt 4700
1931
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 these final rules.
C. Regulatory Flexibility Act
The Regulatory Flexibility Act (RFA)
generally requires an agency to prepare
a regulatory flexibility analysis of any
rule subject to notice and comment
rulemaking requirements under the
Administrative Procedure Act or any
other statute unless the agency certifies
that the rule will not have a significant
economic impact on a substantial
number of small entities. Small entities
include small businesses, small
organizations, and small governmental
jurisdictions.
For the purposes of assessing the
impacts of these final rules on small
entities, small entity is defined as: (1) A
small business whose parent company
has less than $25 million in revenue
(NAICS 447110, Gasoline Stations with
Convenience Stores), less than $23.5
million in revenue (NAICS 484220 and
484230, Hazardous Materials Trucking
[except waste], local and long-distance),
and less than $8.0 million in revenue
(NAICS 447190, Other Gasoline
Stations), and fewer than 100 employees
(NAICS 424710, Petroleum Bulk
Stations and Terminals), and 1,500
employees (NAICS 486910, Pipeline
Transportation of Refined Petroleum
Products) based on Small Business
Administration size standards; (2) a
small governmental jurisdiction that is a
government of a city, county, town,
school district or special district with a
population of less than 50,000; and (3)
a small organization that is any not-forprofit enterprise which is independently
owned and operated and is not
dominant in its field. Under these
definitions, approximately 60,000
gasoline distribution firms are
considered small entities. For more
information, refer to https://
www.sba.gov/size/sizetable2002.html.
The economic impacts of the regulatory
alternatives are analyzed based on the
consumption of gasoline. However, for
the small business impact analysis,
these impacts are described in terms of
comparing the compliance costs to sales
E:\FR\FM\10JAR2.SGM
10JAR2
1932
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
yshivers on PROD1PC62 with RULES2
revenues for representative entities. For
more detail, see the current Economic
Impact Analysis in the public docket.
After considering the economic
impacts of these final rules on small
entities, I certify that the final rules will
not have a significant economic impact
on a substantial number of small
entities. This certification is based on
the economic impact of the final rules
to affected small entities in the entire
gasoline distribution industry. The
small entities directly regulated by these
final rules are industries within the
NAICS codes 424710, 447110, 447190,
484220, and 484230. We have
determined that Pipeline Transportation
of Refined Petroleum Products (NAICS
486910) does not contain any small
business entities and, therefore, is not
included in the small business impact
analysis. For the regulatory alternatives
analyzed, all gasoline distribution
industry categories that contain small
business entities are expected to have an
average annual cost to sales ratio of less
than one percent with cost impacts for
all regulated small entities ranging from
a cost savings to less than 0.61 percent
of sales. In addition, no other adverse
impacts are expected to occur to these
affected small businesses.
For more information on the small
entity economic impacts associated with
the final decisions for gasoline
distribution industries affected by this
action, please refer to the Economic
Impact and Small Business Analyses in
the public docket.
Although these final rules will not
have a significant economic impact on
a substantial number of small entities,
EPA nonetheless has tried to reduce the
impact of these final rules on small
entities. When developing the
standards, we took special steps to
ensure that the burdens imposed on
small entities were minimal. We
conducted meetings with industry
officials to discuss regulatory options
and the corresponding burden on
industry, such as recordkeeping and
reporting.
or more in any one year. Before
promulgating an EPA rule for which a
written statement is needed, section 205
of the UMRA generally requires us 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 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 regulatory proposals
with significant Federal
intergovernmental mandates, and
informing, educating, and advising
small governments on compliance with
the regulatory requirements.
Based on the cost and economic
impact analyses discussed in sections
VI.B and C, and the paperwork analysis
in section VII.B of this preamble, EPA
has determined that these final rules do
not contain a Federal mandate that may
result in expenditures of $100 million or
more to State, local, and tribal
governments in the aggregate, or to the
private sector in any one year. Thus,
these final rules are not subject to the
requirements of sections 202 and 205 of
the UMRA. EPA has determined, for the
same reason as above for all
governments, that these final rules
contain no regulatory requirements that
might significantly or uniquely affect
small governments.
D. Unfunded Mandates Reform Act
Title II of the Unfunded Mandates
Reform Act of 1995 (UMRA), Public
Law 104–4, establishes requirements for
Federal agencies to assess the effects of
their regulatory actions on State, local,
and tribal governments and the private
sector. Under section 202 of 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
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
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
PO 00000
Frm 00018
Fmt 4701
Sfmt 4700
power and responsibilities among the
various levels of government.’’
These final rules do not have
federalism implications. They 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. These final
rules impose requirements on owners
and operators of specified area sources
and not State and local governments.
Thus, Executive Order 13132 does not
apply to these final rules.
F. Executive Order 13175: Consultation
and Coordination With Indian Tribal
Governments
Executive Order 13175, entitled
‘‘Consultation and Coordination with
Indian Tribal Governments’’ (65 FR
67249, November 9, 2000), requires EPA
to develop an accountable process to
ensure ‘‘meaningful and timely input by
tribal officials in the development of
regulatory policies that have tribal
implications.’’
These final rules do not have tribal
implications, as specified in Executive
Order 13175. They will not have
substantial direct effects on tribal
governments, on the relationship
between the Federal government and
Indian tribes, or on the distribution of
power and responsibilities between the
Federal government and Indian tribes.
Thus, Executive Order 13175 does not
apply to these final rules.
G. Executive Order 13045: Protection of
Children From Environmental Health
Risks and Safety Risks
Executive Order 13045 (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,
we 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.
EPA interprets Executive Order 13045
as applying only to those regulatory
actions that are based on health or safety
risks, such that the analysis required
under section 5–501 of the Executive
Order has the potential to influence the
regulation. These final rules are not
subject to Executive Order 13045
because they are based on technology
E:\FR\FM\10JAR2.SGM
10JAR2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
performance and not on health or safety
risks.
yshivers on PROD1PC62 with RULES2
H. Executive Order 13211: Actions
Concerning Regulations That
Significantly Affect Energy Supply,
Distribution, or Use
These final rules are 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 they
are not likely to have a significant
adverse effect on the supply,
distribution, or use of energy. Further,
we have concluded that these final rules
are not likely to have any adverse
energy effects.
I. National Technology Transfer and
Advancement Act
As noted in the proposed rule,
Section 12(d) of the National
Technology Transfer and Advancement
Act (NTTAA) of 1995 (Public Law No.
104–113, 12(d), (15 U.S.C. 272 note)
directs EPA to use voluntary consensus
standards (VCS) in its regulatory
activities, unless to do so would be
inconsistent with applicable law or
otherwise impractical. VCS are
technical standards (e.g., materials
specifications, test methods, sampling
procedures, and business practices) that
are developed or adopted by VCS
bodies. The NTTAA directs EPA to
provide Congress, through OMB,
explanations when the Agency decides
not to use available and applicable VCS.
This rule involves technical
standards. EPA has decided to use the
following methods: EPA Methods 9, 21,
22, and 27 (40 CFR part 60, appendix
A); American Society of Testing
Materials (ASTM) Standard D 5228–92,
‘‘Standard Test Method for
Determination of Butane Working
Capacity of Activated Carbon’’; CARB
Vapor Recovery Test Procedure TP–
201.1, ‘‘Volumetric Efficiency for Phase
I Vapor Recovery Systems’’; CARB
Vapor Recovery Test Procedure TP–
201.1E, ‘‘Leak Rate and Cracking
Pressure of Pressure/Vacuum Vent
Valves’’; and CARB Vapor Recovery
Test Procedure TP–201.3,
‘‘Determination of 2-Inch WC Static
Pressure Performance of Vapor Recovery
Systems of Dispensing Facilities.’’
The standard ASTM D 5228–92,
‘‘Standard Test Method for
Determination of Butane Working
Capacity of Activated Carbon,’’ is also a
VCS. This standard will be incorporated
by reference into 40 CFR 63.14.
Consistent with the NTTAA, EPA
conducted searches to identify VCS in
addition to these methods. No
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
applicable VCS were identified for EPA
Methods 9, 21, 22, 27, ASTM D5228–92,
or CARB methods TP–201.1, TP–201.1E,
and TP–201.3. The search and review
results are in the docket for this rule.
Under 40 CFR 63.7(f) and 40 CFR
63.8(f) of subpart A of the General
Provisions, a source may apply to EPA
for permission to use alternative test
methods or alternative monitoring
requirements in place of any required
testing methods, performance
specifications, or procedures.
J. Executive Order 12898: Federal
Actions To Address Environmental
Justice in Minority Populations and
Low-Income Populations
Executive Order 12898 (59 FR 7629,
February 16, 1994) establishes Federal
executive policy on environmental
justice. Its main provision directs
Federal agencies, to the greatest extent
practicable and permitted by law, to
make environmental justice part of their
mission by identifying and addressing,
as appropriate, disproportionately high
and adverse human health or
environmental effects of their programs,
policies, and activities on minority
populations and low-income
populations in the United States.
EPA has determined that these final
rules will not have disproportionately
high and adverse human health or
environmental effects on minority or
low-income populations because they
increase the level of environmental
protection for all affected populations
without having any disproportionately
high and adverse human health or
environmental effects on any
population, including any minority or
low-income population. These final
rules establish national standards.
K. Congressional Review Act
The Congressional Review Act, 5
U.S.C. 801, et seq., as added by the
Small Business Regulatory Enforcement
Fairness Act of 1996, generally provides
that before a rule may take effect, the
agency promulgating the rule must
submit a rule report, which includes a
copy of the rule, to each House of the
Congress and to the Comptroller General
of the United States. EPA will submit a
report containing these final rules and
other required information to the United
States Senate, the United States House
of Representatives, and the Comptroller
General of the United States prior to
publication of the final rules in the
Federal Register. A major rule cannot
take effect until 60 days after it is
published in the Federal Register. This
action is not a ‘‘major rule’’ as defined
by 5 U.S.C. 804(2). These final rules will
be effective on January 10, 2008.
PO 00000
Frm 00019
Fmt 4701
Sfmt 4700
1933
List of Subjects for 40 CFR Part 63
Environmental protection,
Administrative practice and procedures,
Air pollution control, Incorporations by
reference, Intergovernmental relations,
Reporting and recordkeeping
requirements.
Dated: December 20, 2007.
Stephen L. Johnson,
Administrator.
For the reasons set out in the
preamble, title 40, chapter I, part 63 of
the Code of Federal Regulations is
amended as follows:
I
PART 63—[AMENDED]
1. The authority citation for part 63
continues to read as follows:
I
Authority: 42 U.S.C. 7401, et seq.
2. Section 63.14 is amended by adding
new paragraphs (b)(63) and (l) to read as
follows:
I
§ 63.14
Incorporation by reference.
*
*
*
*
*
(b) * * *
(63) ASTM D 5228–92—‘‘Standard
Test Method for Determination of
Butane Working Capacity of Activated
Carbon,’’ reapproved 2005, IBR
approved for § 63.11092(b)(1)(i)(B)(1)(ii).
*
*
*
*
*
(l) The following materials are
available from the California Air
Resources Board, Engineering and
Certification Branch, 1001 I Street, P.O.
Box 2815, Sacramento, CA 95812–2815,
Telephone (916) 327–0900 and are also
available at the following Web site:
https://www.arb.ca.gov/vapor/vapor.htm.
(1) California Air Resources Board
Vapor Recovery Test Procedure TP–
201.1.—‘‘Volumetric Efficiency for
Phase I Vapor Recovery Systems,’’
adopted April 12, 1996, and amended
February 1, 2001 and October 8, 2003,
IBR approved for § 63.11120(b)(1).
(2) California Air Resources Board
Vapor Recovery Test Procedure TP–
201.1E—‘‘Leak Rate and Cracking
Pressure of Pressure/Vacuum Vent
Valves,’’ adopted October 8, 2003, IBR
approved for § 63.11120(a)(1)(i).
(3) California Air Resources Board
Vapor Recovery Test Procedure TP–
201.3—‘‘Determination of 2-Inch WC
Static Pressure Performance of Vapor
Recovery Systems of Dispensing
Facilities,’’ adopted April 12, 1996 and
amended March 17, 1999, IBR approved
for § 63.11120(a)(2)(i).
3. Part 63 is amended by adding a new
subpart BBBBBB to read as follows:
I
E:\FR\FM\10JAR2.SGM
10JAR2
1934
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
Subpart BBBBBB—National Emission
Standards for Hazardous Air Pollutants
for Source Category: Gasoline
Distribution Bulk Terminals, Bulk
Plants, and Pipeline Facilities
Subpart BBBBBB—National Emission
Standards for Hazardous Air Pollutants
for Source Category: Gasoline
Distribution Bulk Terminals, Bulk
Plants, and Pipeline Facilities
Sec.
What This Subpart Covers
What This Subpart Covers
§ 63.11080
subpart?
63.11080 What is the purpose of this
subpart?
63.11081 Am I subject to the requirements
in this subpart?
63.11082 What parts of my affected source
does this subpart cover?
63.11083 When do I have to comply with
this subpart?
Emission Limitations and Management
Practices
63.11086 What requirements must I meet if
my facility is a bulk gasoline plant?
63.11087 What requirements must I meet
for gasoline storage tanks if my facility
is a bulk gasoline terminal, pipeline
breakout station, or pipeline pumping
station?
63.11088 What requirements must I meet
for gasoline loading racks if my facility
is a bulk gasoline terminal, pipeline
breakout station, or pipeline pumping
station?
63.11089 What requirements must I meet
for equipment leak inspections if my
facility is a bulk gasoline terminal,
pipeline breakout station, or pipeline
pumping station?
Testing and Monitoring Requirements
63.11092 What testing and monitoring
requirements must I meet?
Notification, Records, and Reports
63.11093 What notifications must I submit
and when?
63.11094 What are my recordkeeping
requirements?
63.11095 What are my reporting
requirements?
Other Requirements and Information
63.11098 What parts of the General
Provisions apply to me?
63.11099 Who implements and enforces
this subpart?
63.11100 What definitions apply to this
subpart?
yshivers on PROD1PC62 with RULES2
Tables to Subpart BBBBBB of Part 63
Table 1 to Subpart BBBBBB of Part 63—
Applicability Criteria, Emission Limits,
and Management Practices for Storage
Tanks
Table 2 to Subpart BBBBBB of Part 63—
Applicability Criteria, Emission Limits,
and Management Practices for Loading
Racks
Table 3 to Subpart BBBBBB of Part 63—
Applicability of General Provisions
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
What is the purpose of this
This subpart establishes national
emission limitations and management
practices for hazardous air pollutants
(HAP) emitted from area source gasoline
distribution bulk terminals, bulk plants,
and pipeline facilities. This subpart also
establishes requirements to demonstrate
compliance with the emission
limitations and management practices.
§ 63.11081 Am I subject to the
requirements in this subpart?
(a) The affected source to which this
subpart applies is each area source bulk
gasoline terminal, pipeline breakout
station, pipeline pumping station, and
bulk gasoline plant identified in
paragraphs (a)(1) through (4) of this
section. You are subject to the
requirements in this subpart if you own
or operate one or more of the affected
area sources identified in paragraphs
(a)(1) through (4) of this section.
(1) A bulk gasoline terminal that is
not subject to the control requirements
of 40 CFR part 63, subpart R (§§ 63.422,
63.423, and 63.424) or 40 CFR part 63,
subpart CC (§§ 63.646, 63.648, 63.649,
and 63.650).
(2) A pipeline breakout station that is
not subject to the control requirements
of 40 CFR part 63, subpart R (§§ 63.423
and 63.424).
(3) A pipeline pumping station.
(4) A bulk gasoline plant.
(b) If you are an owner or operator of
affected sources, as defined in (a)(1)
through (4) of this section, you are not
required to meet the obligation to obtain
a permit under 40 CFR part 70 or 40
CFR part 71 as a result of being subject
to this subpart. However, you are still
subject to the requirement to apply for
and obtain a permit under 40 CFR part
70 or 40 CFR part 71 if you meet one
or more of the applicability criteria
found in 40 CFR 70.3(a) and (b) or 40
CFR part 71.3(a) and (b).
§ 63.11082 What parts of my affected
source does this subpart cover?
(a) The emission sources to which this
subpart applies are gasoline storage
tanks, gasoline loading racks, vapor
collection-equipped gasoline cargo
tanks, and equipment components in
vapor or liquid gasoline service that
meet the criteria specified in Tables 1
through 3 to this subpart.
PO 00000
Frm 00020
Fmt 4701
Sfmt 4700
(b) An affected source is a new
affected source if you commenced
construction on the affected source after
November 9, 2006, and you meet the
applicability criteria in § 63.11081 at the
time you commenced operation.
(c) An affected source is reconstructed
if you meet the criteria for
reconstruction as defined in § 63.2.
(d) An affected source is an existing
affected source if it is not new or
reconstructed.
§ 63.11083 When do I have to comply with
this subpart?
(a) If you have a new or reconstructed
affected source, you must comply with
this subpart according to paragraphs
(a)(1) and (2) of this section.
(1) If you start up your affected source
before January 10, 2008, you must
comply with the standards in this
subpart no later than January 10, 2008.
(2) If you start up your affected source
after January 10, 2008, you must comply
with the standards in this subpart upon
startup of your affected source.
(b) If you have an existing affected
source, you must comply with the
standards in this subpart no later than
January 10, 2011.
(c) If you have an existing affected
source that becomes subject to the
control requirements in this subpart
because of an increase in the average
daily throughput, as specified in option
1 of Table 2 to this subpart, you must
comply with the standards in this
subpart no later than 3 years after the
affected source becomes subject to the
control requirements in this subpart.
Emission Limitations and Management
Practices
§ 63.11086 What requirements must I meet
if my facility is a bulk gasoline plant?
Each owner or operator of an affected
bulk gasoline plant, as defined in
§ 63.11100, must comply with the
requirements of paragraphs (a) through
(i) of this section.
(a) Except as specified in paragraph
(b), you must only load gasoline into
storage tanks and cargo tanks at your
facility by utilizing submerged filling, as
defined in § 63.11100, and, as specified
in paragraph (a)(1) or paragraph (a)(2) of
this section.
(1) Submerged fill pipes installed on
or before November 9, 2006, must be no
more than 12 inches from the bottom of
the tank.
(2) Submerged fill pipes installed after
November 9, 2006, must be no more
than 6 inches from the bottom of the
tank.
(b) The emission sources listed in
paragraphs (b)(1) through (2) of this
section are not required to comply with
E:\FR\FM\10JAR2.SGM
10JAR2
yshivers on PROD1PC62 with RULES2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
the control requirements in paragraph
(a) of this section, but must comply only
with the requirements in paragraph (d)
of this section.
(1) Gasoline storage tanks with a
capacity of less than 250 gallons.
(2) Gasoline storage tanks that are
subject to subpart CCCCCC of this part.
(c) You must perform a monthly leak
inspection of all equipment in gasoline
service according to the requirements
specified in § 63.11089(a) through (d).
(d) You must not allow gasoline to be
handled in a manner that would result
in vapor releases to the atmosphere for
extended periods of time. Measures to
be taken include, but are not limited to,
the following:
(1) Minimize gasoline spills;
(2) Clean up spills as expeditiously as
practicable;
(3) Cover all open gasoline containers
and all gasoline storage tank fill-pipes
with a gasketed seal when not in use;
(4) Minimize gasoline sent to open
waste collection systems that collect
and transport gasoline to reclamation
and recycling devices, such as oil/water
separators.
(e) You must submit an Initial
Notification that you are subject to this
subpart by May 9, 2008 unless you meet
the requirements in paragraph (g) of this
section. The Initial Notification must
contain the information specified in
paragraphs (e)(1) through (4) of this
section. The notification must be
submitted to the applicable EPA
Regional Office and the delegated State
authority, as specified in § 63.13.
(1) The name and address of the
owner and the operator.
(2) The address (i.e., physical
location) of the bulk plant.
(3) A statement that the notification is
being submitted in response to this
subpart and identifying the
requirements in paragraphs (a), (b), (c),
and (d) of this section that apply to you.
(4) A brief description of the bulk
plant, including the number of storage
tanks in gasoline service, the capacity of
each storage tank in gasoline service,
and the average monthly gasoline
throughput at the affected source.
(f) You must submit a Notification of
Compliance Status to the applicable
EPA Regional Office and the delegated
State authority, as specified in § 63.13,
by the compliance date specified in
§ 63.11083 unless you meet the
requirements in paragraph (g) of this
section. The Notification of Compliance
Status must be signed by a responsible
official who must certify its accuracy
and must indicate whether the source
has complied with the requirements of
this subpart. If your facility is in
compliance with the requirements of
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
this subpart at the time the Initial
Notification required under paragraph
(e) of this section is due, the
Notification of Compliance Status may
be submitted in lieu of the Initial
Notification provided it contains the
information required under paragraph
(e) of this section.
(g) If, prior to January 10, 2008, you
are operating in compliance with an
enforceable State, local, or tribal rule or
permit that requires submerged fill as
specified in § 63.11086(a), you are not
required to submit an Initial
Notification or a Notification of
Compliance Status under paragraph (e)
or paragraph (f) of this section.
(h) You must comply with the
requirements of this subpart by the
applicable dates specified in § 63.11083.
(i) You must keep applicable records
and submit reports as specified in
§ 63.11094(d) and (e) and § 63.11095(c).
§ 63.11087 What requirements must I meet
for gasoline storage tanks if my facility is
a bulk gasoline terminal, pipeline breakout
station, or pipeline pumping station?
(a) You must meet each emission limit
and management practice in Table 1 to
this subpart that applies to your
gasoline storage tank.
(b) You must comply with the
requirements of this subpart by the
applicable dates specified in § 63.11083,
except that storage vessels equipped
with floating roofs and not meeting the
requirements of paragraph (a) of this
section must be in compliance at the
first degassing and cleaning activity
after January 10, 2011 or by January 10,
2018, whichever is first.
(c) You must comply with the
applicable testing and monitoring
requirements specified in § 63.11092(e).
(d) You must submit the applicable
notifications as required under
§ 63.11093.
(e) You must keep records and submit
reports as specified in §§ 63.11094 and
63.11095.
(f) If your gasoline storage tank is
subject to, and complies with, the
control requirements of 40 CFR part 60,
subpart Kb of this chapter, your storage
tank will be deemed in compliance with
this section. You must report this
determination in the Notification of
Compliance Status report under
§ 63.11093(b).
§ 63.11088 What requirements must I meet
for gasoline loading racks if my facility is
a bulk gasoline terminal, pipeline breakout
station, or pipeline pumping station?
(a) You must meet each emission limit
and management practice in Table 2 to
this subpart that applies to you.
(b) As an alternative for railcar cargo
tanks to the requirements specified in
PO 00000
Frm 00021
Fmt 4701
Sfmt 4700
1935
Table 2 to this subpart, you may comply
with the requirements specified in
§ 63.422(e).
(c) You must comply with the
requirements of this subpart by the
applicable dates specified in § 63.11083.
(d) You must comply with the
applicable testing and monitoring
requirements specified in § 63.11092.
(e) You must submit the applicable
notifications as required under
§ 63.11093.
(f) You must keep records and submit
reports as specified in §§ 63.11094 and
63.11095.
§ 63.11089 What requirements must I meet
for equipment leak inspections if my facility
is a bulk gasoline terminal, bulk plant,
pipeline breakout station, or pipeline
pumping station?
(a) Each owner or operator of a bulk
gasoline terminal, bulk plant, pipeline
breakout station, or pipeline pumping
station subject to the provisions of this
subpart shall perform a monthly leak
inspection of all equipment in gasoline
service, as defined in § 63.11100. For
this inspection, detection methods
incorporating sight, sound, and smell
are acceptable.
(b) A log book shall be used and shall
be signed by the owner or operator at
the completion of each inspection. A
section of the log book shall contain a
list, summary description, or diagram(s)
showing the location of all equipment in
gasoline service at the facility.
(c) Each detection of a liquid or vapor
leak shall be recorded in the log book.
When a leak is detected, an initial
attempt at repair shall be made as soon
as practicable, but no later than 5
calendar days after the leak is detected.
Repair or replacement of leaking
equipment shall be completed within 15
calendar days after detection of each
leak, except as provided in paragraph
(d) of this section.
(d) Delay of repair of leaking
equipment will be allowed if the repair
is not feasible within 15 days. The
owner or operator shall provide in the
semiannual report specified in
§ 63.11095(b), the reason(s) why the
repair was not feasible and the date each
repair was completed.
(e) You must comply with the
requirements of this subpart by the
applicable dates specified in § 63.11083.
(f) You must submit the applicable
notifications as required under
§ 63.11093.
(g) You must keep records and submit
reports as specified in §§ 63.11094 and
63.11095.
E:\FR\FM\10JAR2.SGM
10JAR2
1936
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
Testing and Monitoring Requirements
yshivers on PROD1PC62 with RULES2
§ 63.11092 What testing and monitoring
requirements must I meet?
(a) Each owner or operator subject to
the emission standard in § 63.11088 for
gasoline loading racks must comply
with the requirements in paragraphs (a)
through (d) of this section.
(1) Conduct a performance test on the
vapor processing and collection systems
according to either paragraph (a)(1)(i) or
paragraph (a)(1)(ii) of this section.
(i) Use the test methods and
procedures in § 60.503 of this chapter,
except a reading of 500 parts per million
shall be used to determine the level of
leaks to be repaired under § 60.503(b) of
this chapter.
(ii) Use alternative test methods and
procedures in accordance with the
alternative test method requirements in
§ 63.7(f).
(2) If you are operating your gasoline
loading rack in compliance with an
enforceable State, local, or tribal rule or
permit that requires your loading rack to
meet an emission limit of 80 milligrams
(mg), or less, per liter of gasoline loaded
(mg/l), you may submit a statement by
a responsible official of your facility
certifying the compliance status of your
loading rack in lieu of the test required
under paragraph (a)(1) of this section.
(3) If you have conducted
performance testing on the vapor
processing and collection systems
within 5 years prior to January 10, 2008,
and the test is for the affected facility
and is representative of current or
anticipated operating processes and
conditions, you may submit the results
of such testing in lieu of the test
required under paragraph (a)(1) of this
section, provided the testing was
conducted using the test methods and
procedures in § 60.503 of this chapter.
Should the Administrator deem the
prior test data unacceptable, the facility
is still required to meet the requirement
to conduct an initial performance test
within 180 days of the rule
promulgation; thus, previous test
reports should be submitted as soon as
possible after January 10, 2008.
(4) The performance test requirements
of § 63.11092(a) do not apply to flares
defined in § 63.11100 and meeting the
flare requirements in § 63.11(b). The
owner or operator shall demonstrate
that the flare and associated vapor
collection system is in compliance with
the requirements in § 63.11(b) and 40
CFR 60.503(a), (b), and (d).
(b) For each performance test
conducted under paragraph (a)(1) of this
section, the owner or operator shall
determine a monitored operating
parameter value for the vapor
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
processing system using the procedures
specified in paragraphs (b)(1) through
(5) of this section.
(1) Each owner or operator of a bulk
gasoline terminal subject to the
provisions of this subpart shall install,
calibrate, certify, operate, and maintain,
according to the manufacturer’s
specifications, a continuous monitoring
system (CMS) while gasoline vapors are
displaced to the vapor processor
systems specified in paragraphs (b)(1)(i)
through (iv) of this section. During the
performance test, continuously record
the operating parameter as specified
under paragraphs (b)(1)(i) through (iv) of
this section.
(i) Where a carbon adsorption system
is used, the owner or operator shall
monitor the operation of the system as
specified in paragraphs (b)(1)(i)(A) or
(B) of this section.
(A) A continuous emissions
monitoring system (CEMS) capable of
measuring organic compound
concentration shall be installed in the
exhaust air stream.
(B) As an alternative to paragraph
(b)(1)(i)(A) of this section, you may
choose to meet the requirements listed
in paragraph (b)(1)(i)(B)(1) and (2) of
this section.
(1) Carbon adsorption devices shall be
monitored as specified in paragraphs
(b)(1)(i)(B)(1)(i),(ii), and (iii) of this
section.
(i) Vacuum level shall be monitored
using a pressure transmitter installed in
the vacuum pump suction line, with the
measurements displayed on a gauge that
can be visually observed. Each carbon
bed shall be observed during one
complete regeneration cycle on each day
of operation of the loading rack to
determine the maximum vacuum level
achieved.
(ii) Conduct annual testing of the
carbon activity for the carbon in each
carbon bed. Carbon activity shall be
tested in accordance with the butane
working capacity test of the American
Society for Testing and Materials
(ASTM) Method D 5228–92
(incorporated by reference, see § 63.14),
or by another suitable procedure as
recommended by the manufacturer.
(iii) Conduct monthly measurements
of the carbon bed outlet volatile organic
compounds (VOC) concentration over
the last 5 minutes of an adsorption cycle
for each carbon bed, documenting the
highest measured VOC concentration.
Measurements shall be made using a
portable analyzer, in accordance with 40
CFR part 60, Appendix A–7, EPA
Method 21 for open-ended lines.
(2) Develop and submit to the
Administrator a monitoring and
inspection plan that describes the owner
PO 00000
Frm 00022
Fmt 4701
Sfmt 4700
or operator’s approach for meeting the
requirements in paragraphs
(b)(1)(i)(B)(2)(i) through (v) of this
section.
(i) The lowest maximum required
vacuum level and duration needed to
assure regeneration of the carbon beds
shall be determined by an engineering
analysis or from the manufacturer’s
recommendation and shall be
documented in the monitoring and
inspection plan.
(ii) The owner or operator shall verify,
during each day of operation of the
loading rack, the proper valve
sequencing, cycle time, gasoline flow,
purge air flow, and operating
temperatures. Verification shall be
through visual observation or through
an automated alarm or shutdown system
that monitors and records system
operation.
(iii) The owner or operator shall
perform semi-annual preventive
maintenance inspections of the carbon
adsorption system according to the
recommendations of the manufacturer
of the system.
(iv) The monitoring plan developed
under paragraph (2) of this section shall
specify conditions that would be
considered malfunctions of the carbon
adsorption system during the
inspections or automated monitoring
performed under paragraphs
(b)(1)(i)(B)(2)(i) through (iii) of this
section, describe specific corrective
actions that will be taken to correct any
malfunction, and define what the owner
or operator would consider to be a
timely repair for each potential
malfunction.
(v) The owner or operator shall
document the maximum vacuum level
observed on each carbon bed from each
daily inspection and the maximum VOC
concentration observed from each
carbon bed on each monthly inspection
as well as any system malfunction, as
defined in the monitoring and
inspection plan, and any activation of
the automated alarm or shutdown
system with a written entry into a log
book or other permanent form of record.
Such record shall also include a
description of the corrective action
taken and whether such corrective
actions were taken in a timely manner,
as defined in the monitoring and
inspection plan, as well as an estimate
of the amount of gasoline loaded during
the period of the malfunction.
(ii) Where a refrigeration condenser
system is used, a continuous parameter
monitoring system (CPMS) capable of
measuring temperature shall be
installed immediately downstream from
the outlet to the condenser section.
Alternatively, a CEMS capable of
E:\FR\FM\10JAR2.SGM
10JAR2
yshivers on PROD1PC62 with RULES2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
measuring organic compound
concentration may be installed in the
exhaust air stream.
(iii) Where a thermal oxidation system
other than a flare is used, the owner or
operator shall monitor the operation of
the system as specified in paragraphs
(b)(1)(iii)(A) or (B) of this section.
(A) A CPMS capable of measuring
temperature shall be installed in the
firebox or in the ductwork immediately
downstream from the firebox in a
position before any substantial heat
exchange occurs.
(B) As an alternative to paragraph
(b)(1)(iii)(A) of this section, you may
choose to meet the requirements listed
in paragraphs (b)(1)(iii)(B)(1) and (2) of
this section.
(1) The presence of a thermal
oxidation system pilot flame shall be
monitored using a heat-sensing device,
such as an ultraviolet beam sensor or a
thermocouple, installed in proximity to
the pilot light to indicate the presence
of a flame.
(2) Develop and submit to the
Administrator a monitoring and
inspection plan that describes the owner
or operator’s approach for meeting the
requirements in paragraphs
(b)(1)(iii)(B)(2)(i) through (v) of this
section.
(i) The thermal oxidation system shall
be equipped to automatically prevent
gasoline loading operations from
beginning at any time that the pilot
flame is absent.
(ii) The owner or operator shall verify,
during each day of operation of the
loading rack, the proper operation of the
assist-air blower, the vapor line valve,
and the emergency shutdown system.
Verification shall be through visual
observation or through an automated
alarm or shutdown system that monitors
and records system operation.
(iii) The owner or operator shall
perform semi-annual preventive
maintenance inspections of the thermal
oxidation system according to the
recommendations of the manufacturer
of the system.
(iv) The monitoring plan developed
under paragraph (2) of this section shall
specify conditions that would be
considered malfunctions of the thermal
oxidation system during the inspections
or automated monitoring performed
under paragraphs (b)(1)(iii)(B)(2)(ii) and
(iii) of this section, describe specific
corrective actions that will be taken to
correct any malfunction, and define
what the owner or operator would
consider to be a timely repair for each
potential malfunction.
(v) The owner or operator shall
document any system malfunction, as
defined in the monitoring and
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
inspection plan, and any activation of
the automated alarm or shutdown
system with a written entry into a log
book or other permanent form of record.
Such record shall also include a
description of the corrective action
taken and whether such corrective
actions were taken in a timely manner,
as defined in the monitoring and
inspection plan, as well as an estimate
of the amount of gasoline loaded during
the period of the malfunction.
(iv) Monitoring an alternative
operating parameter or a parameter of a
vapor processing system other than
those listed in paragraphs (b)(1)(i)
through (iii) of this section will be
allowed upon demonstrating to the
Administrator’s satisfaction that the
alternative parameter demonstrates
continuous compliance with the
emission standard in § 63.11088(a).
(2) Where a flare meeting the
requirements in § 63.11(b) is used, a
heat-sensing device, such as an
ultraviolet beam sensor or a
thermocouple, must be installed in
proximity to the pilot light to indicate
the presence of a flame.
(3) Determine an operating parameter
value based on the parameter data
monitored during the performance test,
supplemented by engineering
assessments and the manufacturer’s
recommendations.
(4) Provide for the Administrator’s
approval the rationale for the selected
operating parameter value, monitoring
frequency, and averaging time,
including data and calculations used to
develop the value and a description of
why the value, monitoring frequency,
and averaging time demonstrate
continuous compliance with the
emission standard in § 63.11088(a).
(5) If you have chosen to comply with
the performance testing alternatives
provided under paragraph (a)(2) or
paragraph (a)(3) of this section, the
monitored operating parameter value
may be determined according to the
provisions in paragraph (b)(5)(i) or
paragraph (b)(5)(ii) of this section.
(i) Monitor an operating parameter
that has been approved by the
Administrator and is specified in your
facility’s current enforceable operating
permit. At the time that the
Administrator requires a new
performance test, you must determine
the monitored operating parameter
value according to the requirements
specified in paragraph (b) of this
section.
(ii) Determine an operating parameter
value based on engineering assessment
and the manufacturer’s recommendation
and submit the information specified in
paragraph (b)(4) of this section for
PO 00000
Frm 00023
Fmt 4701
Sfmt 4700
1937
approval by the Administrator. At the
time that the Administrator requires a
new performance test, you must
determine the monitored operating
parameter value according to the
requirements specified in paragraph (b)
of this section.
(c) For performance tests performed
after the initial test required under
paragraph (a) of this section, the owner
or operator shall document the reasons
for any change in the operating
parameter value since the previous
performance test.
(d) Each owner or operator of a bulk
gasoline terminal subject to the
provisions of this subpart shall comply
with the requirements in paragraphs
(d)(1) through (4) of this section.
(1) Operate the vapor processing
system in a manner not to exceed or not
to go below, as appropriate, the
operating parameter value for the
parameters described in paragraph (b)(1)
of this section.
(2) In cases where an alternative
parameter pursuant to paragraph
(b)(1)(iv) or paragraph (b)(5)(i) of this
section is approved, each owner or
operator shall operate the vapor
processing system in a manner not to
exceed or not to go below, as
appropriate, the alternative operating
parameter value.
(3) Operation of the vapor processing
system in a manner exceeding or going
below the operating parameter value, as
appropriate, shall constitute a violation
of the emission standard in
§ 63.11088(a), except as specified in
paragraph (d)(4) of this section.
(4) For the monitoring and inspection,
as required under paragraphs
(b)(1)(i)(B)(2) and (b)(1)(iii)(B)(2) of this
section, malfunctions that are
discovered shall not constitute a
violation of the emission standard in
§ 63.11088(a) if corrective actions as
described in the monitoring and
inspection plan are followed. The owner
or operator must:
(i) Initiate corrective action to
determine the cause of the problem
within 1 hour;
(ii) Initiate corrective action to fix the
problem within 24 hours;
(iii) Complete all corrective actions
needed to fix the problem as soon as
practicable consistent with good air
pollution control practices for
minimizing emissions;
(iv) Minimize periods of start-up,
shutdown, or malfunction; and
(v) Take any necessary corrective
actions to restore normal operation and
prevent the recurrence of the cause of
the problem.
(e) Each owner or operator subject to
the emission standard in § 63.11087 for
E:\FR\FM\10JAR2.SGM
10JAR2
yshivers on PROD1PC62 with RULES2
1938
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
gasoline storage tanks shall comply with
the requirements in paragraphs (e)(1)
through (3) of this section.
(1) If your gasoline storage tank is
equipped with an internal floating roof,
you must perform inspections of the
floating roof system according to the
requirements of § 60.113b(a) if you are
complying with option 2(b) in Table 1
to this subpart, or according to the
requirements of § 63.1063(c)(1) if you
are complying with option 2(d) in Table
1 to this subpart.
(2) If your gasoline storage tank is
equipped with an external floating roof,
you must perform inspections of the
floating roof system according to the
requirements of § 60.113b(b) if you are
complying with option 2(c) in Table 1
to this subpart, or according to the
requirements of § 63.1063(c)(2) if you
are complying with option 2(d) in Table
1 to this subpart.
(3) If your gasoline storage tank is
equipped with a closed vent system and
control device, you must conduct a
performance test and determine a
monitored operating parameter value in
accordance with the requirements in
paragraphs (a) through (d) of this
section, except that the applicable level
of control specified in paragraph (a)(2)
of this section shall be a 95-percent
reduction in inlet total organic
compounds (TOC) levels rather than 80
mg/l of gasoline loaded.
(f) The annual certification test for
gasoline cargo tanks shall consist of the
test methods specified in paragraphs
(f)(1) or (f)(2) of this section.
(1) EPA Method 27, Appendix A–8, 40
CFR part 60. Conduct the test using a
time period (t) for the pressure and
vacuum tests of 5 minutes. The initial
pressure (Pi) for the pressure test shall
be 460 millimeters (mm) of water (18
inches of water), gauge. The initial
vacuum (Vi) for the vacuum test shall be
150 mm of water (6 inches of water),
gauge. The maximum allowable
pressure and vacuum changes (D p, D v)
for all affected gasoline cargo tanks is 3
inches of water, or less, in 5 minutes.
(2) Railcar bubble leak test
procedures. As an alternative to the
annual certification test required under
paragraph (1) of this section for
certification leakage testing of gasoline
cargo tanks, the owner or operator may
comply with paragraphs (f)(2)(i) and (ii)
of this section for railcar cargo tanks,
provided the railcar cargo tank meets
the requirement in paragraph (f)(2)(iii)
of this section.
(i) Comply with the requirements of
49 CFR 173.31(d), 49 CFR 179.7, 49 CFR
180.509, and 49 CFR 180.511 for the
periodic testing of railcar cargo tanks.
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
(ii) The leakage pressure test
procedure required under 49 CFR
180.509(j) and used to show no
indication of leakage under 49 CFR
180.511(f) shall be ASTM E 515–95, BS
EN 1593:1999, or another bubble leak
test procedure meeting the requirements
in 49 CFR 179.7, 49 CFR 180.505, and
49 CFR 180.509.
(iii) The alternative requirements in
this paragraph (f)(2) may not be used for
any railcar cargo tank that collects
gasoline vapors from a vapor balance
system and the system complies with a
Federal, State, local, or tribal rule or
permit. A vapor balance system is a
piping and collection system designed
to collect gasoline vapors displaced
from a storage vessel, barge, or other
container being loaded, and routes the
displaced gasoline vapors into the
railcar cargo tank from which liquid
gasoline is being unloaded.
Notifications, Records, and Reports
§ 63.11093 What notifications must I
submit and when?
(a) Each owner or operator of an
affected source under this subpart must
submit an Initial Notification as
specified in § 63.9(b). If your facility is
in compliance with the requirements of
this subpart at the time the Initial
Notification is due, the Notification of
Compliance Status required under
paragraph (b) of this section may be
submitted in lieu of the Initial
Notification.
(b) Each owner or operator of an
affected source under this subpart must
submit a Notification of Compliance
Status as specified in § 63.9(h). The
Notification of Compliance Status must
specify which of the compliance options
included in Table 1 to this subpart is
used to comply with this subpart.
(c) Each owner or operator of an
affected bulk gasoline terminal under
this subpart must submit a Notification
of Performance Test, as specified in
§ 63.9(e), prior to initiating testing
required by § 63.11092(a) or
§ 63.11092(b).
(d) Each owner or operator of any
affected source under this subpart must
submit additional notifications specified
in § 63.9, as applicable.
§ 63.11094 What are my recordkeeping
requirements?
(a) Each owner or operator of a bulk
gasoline terminal or pipeline breakout
station whose storage vessels are subject
to the provisions of this subpart shall
keep records as specified in § 60.115b of
this chapter if you are complying with
options 2(a), 2(b), or 2(c) in Table 1 to
this subpart, except records shall be
kept for at least 5 years. If you are
PO 00000
Frm 00024
Fmt 4701
Sfmt 4700
complying with the requirements of
option 2(d) in Table 1 to this subpart,
you shall keep records as specified in
§ 63.1065.
(b) Each owner or operator of a bulk
gasoline terminal subject to the
provisions of this subpart shall keep
records of the test results for each
gasoline cargo tank loading at the
facility as specified in paragraphs (b)(1)
through (3) of this section.
(1) Annual certification testing
performed under § 63.11092(f)(1) and
periodic railcar bubble leak testing
performed under § 63.11092(f)(2).
(2) The documentation file shall be
kept up-to-date for each gasoline cargo
tank loading at the facility. The
documentation for each test shall
include, as a minimum, the following
information:
(i) Name of test: Annual Certification
Test—Method 27 or Periodic Railcar
Bubble Leak Test Procedure.
(ii) Cargo tank owner’s name and
address.
(iii) Cargo tank identification number.
(iv) Test location and date.
(v) Tester name and signature.
(vi) Witnessing inspector, if any:
Name, signature, and affiliation.
(vii) Vapor tightness repair: Nature of
repair work and when performed in
relation to vapor tightness testing.
(viii) Test results: Test pressure;
pressure or vacuum change, mm of
water; time period of test; number of
leaks found with instrument; and leak
definition.
(3) If you are complying with the
alternative requirements in
§ 63.11088(b), you must keep records
documenting that you have verified the
vapor tightness testing according to the
requirements of the Administrator.
(c) As an alternative to keeping
records at the terminal of each gasoline
cargo tank test result as required in
paragraph (b) of this section, an owner
or operator may comply with the
requirements in either paragraph (c)(1)
or paragraph (c)(2) of this section.
(1) An electronic copy of each record
is instantly available at the terminal.
(i) The copy of each record in
paragraph (c)(1) of this section is an
exact duplicate image of the original
paper record with certifying signatures.
(ii) The Administrator is notified in
writing that each terminal using this
alternative is in compliance with
paragraph (c)(1) of this section.
(2) For facilities that use a terminal
automation system to prevent gasoline
cargo tanks that do not have valid cargo
tank vapor tightness documentation
from loading (e.g., via a card lock-out
system), a copy of the documentation is
made available (e.g., via facsimile) for
E:\FR\FM\10JAR2.SGM
10JAR2
yshivers on PROD1PC62 with RULES2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
inspection by the Administrator’s
delegated representatives during the
course of a site visit, or within a
mutually agreeable time frame.
(i) The copy of each record in
paragraph (c)(2) of this section is an
exact duplicate image of the original
paper record with certifying signatures.
(ii) The Administrator is notified in
writing that each terminal using this
alternative is in compliance with
paragraph (c)(2) of this section.
(d) Each owner or operator subject to
the equipment leak provisions of
§ 63.11089 shall prepare and maintain a
record describing the types,
identification numbers, and locations of
all equipment in gasoline service. For
facilities electing to implement an
instrument program under § 63.11089,
the record shall contain a full
description of the program.
(e) Each owner or operator of an
affected source subject to equipment
leak inspections under § 63.11089 shall
record in the log book for each leak that
is detected the information specified in
paragraphs (e)(1) through (7) of this
section.
(1) The equipment type and
identification number.
(2) The nature of the leak (i.e., vapor
or liquid) and the method of detection
(i.e., sight, sound, or smell).
(3) The date the leak was detected and
the date of each attempt to repair the
leak.
(4) Repair methods applied in each
attempt to repair the leak.
(5) ‘‘Repair delayed’’ and the reason
for the delay if the leak is not repaired
within 15 calendar days after discovery
of the leak.
(6) The expected date of successful
repair of the leak if the leak is not
repaired within 15 days.
(7) The date of successful repair of the
leak.
(f) Each owner or operator of a bulk
gasoline terminal subject to the
provisions of this subpart shall:
(1) Keep an up-to-date, readily
accessible record of the continuous
monitoring data required under
§ 63.11092(b) or § 63.11092(e). This
record shall indicate the time intervals
during which loadings of gasoline cargo
tanks have occurred or, alternatively,
shall record the operating parameter
data only during such loadings. The
date and time of day shall also be
indicated at reasonable intervals on this
record.
(2) Record and report simultaneously
with the Notification of Compliance
Status required under § 63.11093(b):
(i) All data and calculations,
engineering assessments, and
manufacturer’s recommendations used
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
in determining the operating parameter
value under § 63.11092(b) or
§ 63.11092(e); and
(ii) The following information when
using a flare under provisions of
§ 63.11(b) to comply with § 63.11087(a):
(A) Flare design (i.e., steam-assisted,
air-assisted, or non-assisted); and
(B) All visible emissions (VE)
readings, heat content determinations,
flow rate measurements, and exit
velocity determinations made during
the compliance determination required
under § 63.11092(e)(3).
(3) Keep an up-to-date, readily
accessible copy of the monitoring and
inspection plan required under
§ 63.11092(b)(1)(i)(B)(2) or
§ 63.11092(b)(1)(iii)(B)(2).
(4) Keep an up-to-date, readily
accessible record of all system
malfunctions, as specified in
§ 63.11092(b)(1)(i)(B)(2)(v) or
§ 63.11092(b)(1)(iii)(B)(2)(v).
(5) If an owner or operator requests
approval to use a vapor processing
system or monitor an operating
parameter other than those specified in
§ 63.11092(b), the owner or operator
shall submit a description of planned
reporting and recordkeeping
procedures.
§ 63.11095 What are my reporting
requirements?
(a) Each owner or operator of a bulk
terminal or a pipeline breakout station
subject to the control requirements of
this subpart shall include in a
semiannual compliance report to the
Administrator the following
information, as applicable:
(1) For storage vessels, if you are
complying with options 2(a), 2(b), or
2(c) in Table 1 to this subpart, the
information specified in § 60.115b(a),
§ 60.115b(b), or § 60.115b(c) of this
chapter, depending upon the control
equipment installed, or, if you are
complying with option 2(d) in Table 1
to this subpart, the information
specified in § 63.1066.
(2) For loading racks, each loading of
a gasoline cargo tank for which vapor
tightness documentation had not been
previously obtained by the facility.
(3) For equipment leak inspections,
the number of equipment leaks not
repaired within 15 days after detection.
(b) Each owner or operator of an
affected source subject to the control
requirements of this subpart shall
submit an excess emissions report to the
Administrator at the time the
semiannual compliance report is
submitted. Excess emissions events
under this subpart, and the information
to be included in the excess emissions
PO 00000
Frm 00025
Fmt 4701
Sfmt 4700
1939
report, are specified in paragraphs (b)(1)
through (5) of this section.
(1) Each instance of a non-vapor-tight
gasoline cargo tank loading at the
facility in which the owner or operator
failed to take steps to assure that such
cargo tank would not be reloaded at the
facility before vapor tightness
documentation for that cargo tank was
obtained.
(2) Each reloading of a non-vaportight gasoline cargo tank at the facility
before vapor tightness documentation
for that cargo tank is obtained by the
facility in accordance with
§ 63.11094(b).
(3) Each exceedance or failure to
maintain, as appropriate, the monitored
operating parameter value determined
under § 63.11092(b). The report shall
include the monitoring data for the days
on which exceedances or failures to
maintain have occurred, and a
description and timing of the steps
taken to repair or perform maintenance
on the vapor collection and processing
systems or the CMS.
(4) Each instance in which
malfunctions discovered during the
monitoring and inspections required
under § 63.11092(b)(1)(i)(B)(2) and
(b)(1)(iii)(B)(2) were not resolved
according to the necessary corrective
actions described in the monitoring and
inspection plan. The report shall
include a description of the malfunction
and the timing of the steps taken to
correct the malfunction.
(5) For each occurrence of an
equipment leak for which no repair
attempt was made within 5 days or for
which repair was not completed within
15 days after detection:
(i) The date on which the leak was
detected;
(ii) The date of each attempt to repair
the leak;
(iii) The reasons for the delay of
repair; and
(iv) The date of successful repair.
(c) Each owner or operator of a bulk
gasoline plant or a pipeline pumping
station shall submit a semiannual excess
emissions report, including the
information specified in paragraphs
(a)(3) and (b)(4) of this section, only for
a 6-month period during which an
excess emission event has occurred. If
no excess emission events have
occurred during the previous 6-month
period, no report is required.
Other Requirements and Information
§ 63.11098 What parts of the General
Provisions apply to me?
Table 3 to this subpart shows which
parts of the General Provisions apply to
you.
E:\FR\FM\10JAR2.SGM
10JAR2
1940
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
§ 63.11099 Who implements and enforces
this subpart?
(a) This subpart can be implemented
and enforced by the U.S. EPA or a
delegated authority such as the
applicable State, local, or tribal agency.
If the U.S. EPA Administrator has
delegated authority to a State, local, or
tribal agency, then that agency, in
addition to the U.S. EPA, has the
authority to implement and enforce this
subpart. Contact the applicable U.S.
EPA Regional Office to find out if
implementation and enforcement of this
subpart is delegated to a State, local, or
tribal agency.
(b) In delegating implementation and
enforcement authority of this subpart to
a State, local, or tribal agency under
subpart E of this part, the authorities
specified in paragraph (c) of this section
are retained by the Administrator of
U.S. EPA and cannot be transferred to
the State, local, or tribal agency.
(c) The authorities that cannot be
delegated to State, local, or tribal
agencies are as specified in paragraphs
(c)(1) through (4) of this section.
(1) Approval of alternatives to the
requirements in §§ 63.11086 through
63.11088 and § 63.11092. Any owner or
operator requesting to use an alternative
means of emission limitation for storage
vessels in Table 1 to this subpart must
follow either the provisions in § 60.114b
of this chapter if you are complying
with options 2(a), 2(b), or 2(c) in Table
1 to this subpart, or the provisions in
§ 63.1064 if you are complying with
option 2(d) in Table 1 to this subpart.
(2) Approval of major alternatives to
test methods under § 63.7(e)(2)(ii) and
(f), as defined in § 63.90, and as required
in this subpart.
(3) Approval of major alternatives to
monitoring under § 63.8(f), as defined in
§ 63.90, and as required in this subpart.
(4) Approval of major alternatives to
recordkeeping and reporting under
§ 63.10(f), as defined in § 63.90, and as
required in this subpart.
§ 63.11100
subpart?
What definitions apply to this
As used in this subpart, all terms not
defined herein shall have the meaning
given them in the Clean Air Act (CAA),
in subparts A, K, Ka, Kb, and XX of part
60 of this chapter, or in subparts A, R,
and WW of this part. All terms defined
in both subpart A of part 60 of this
chapter and subparts A, R, and WW of
this part shall have the meaning given
in subparts A, R, and WW of this part.
For purposes of this subpart, definitions
in this section supersede definitions in
other parts or subparts.
Administrator means the
Administrator of the United States
Environmental Protection Agency or his
or her authorized representative (e.g., a
State that has been delegated the
authority to implement the provisions of
this subpart).
Bulk gasoline plant means any
gasoline storage and distribution facility
that receives gasoline by pipeline, ship
or barge, or cargo tank and has a
gasoline throughput of less than 20,000
gallons per day. Gasoline throughput
shall be the maximum calculated design
throughput as may be limited by
compliance with an enforceable
condition under Federal, State, or local
law and discoverable by the
Administrator and any other person.
Bulk gasoline terminal means any
gasoline storage and distribution facility
that receives gasoline by pipeline, ship
or barge, or cargo tank and has a
gasoline throughput of 20,000 gallons
per day or greater. Gasoline throughput
shall be the maximum calculated design
throughput as may be limited by
compliance with an enforceable
condition under Federal, State, or local
law and discoverable by the
Administrator and any other person.
Equipment means each valve, pump,
pressure relief device, sampling
connection system, open-ended valve or
line, and flange or other connector in
the gasoline liquid transfer and vapor
collection systems. This definition also
includes the entire vapor processing
system except the exhaust port(s) or
stack(s).
Flare means a thermal oxidation
system using an open (without
enclosure) flame.
Gasoline cargo tank means a delivery
tank truck or railcar which is loading
gasoline or which has loaded gasoline
on the immediately previous load.
In gasoline service means that a piece
of equipment is used in a system that
transfers gasoline or gasoline vapors.
Monthly means once per calendar
month at regular intervals of no less
than 28 days and no more than 35 days.
Operating parameter value means a
value for an operating or emission
parameter of the vapor processing
system (e.g., temperature) which, if
maintained continuously by itself or in
combination with one or more other
operating parameter values, determines
that an owner or operator has complied
with the applicable emission standard.
The operating parameter value is
determined using the procedures
specified in § 63.11092(b).
Pipeline breakout station means a
facility along a pipeline containing
storage vessels used to relieve surges or
receive and store gasoline from the
pipeline for re-injection and continued
transportation by pipeline or to other
facilities.
Pipeline pumping station means a
facility along a pipeline containing
pumps to maintain the desired pressure
and flow of product through the
pipeline and not containing storage
vessels.
Submerged filling means, for the
purposes of this subpart, the filling of a
gasoline cargo tank or a stationary
storage tank through a submerged fill
pipe whose discharge is no more than
the applicable distance specified in
§ 63.11086(a) from the bottom of the
tank. Bottom filling of gasoline cargo
tanks or storage tanks is included in this
definition.
Vapor collection-equipped gasoline
cargo tank means a gasoline cargo tank
that is outfitted with the equipment
necessary to transfer vapors, displaced
during the loading of gasoline into the
cargo tank, to a vapor processor system.
Vapor-tight gasoline cargo tank means
the same as the definition of the term
‘‘vapor-tight gasoline tank truck’’ in
§ 60.501, except that for this subpart the
term ‘‘gasoline tank truck’’ means
‘‘gasoline cargo tank,’’ as defined in this
section.
TABLE 1 TO SUBPART BBBBBB OF PART 63.—APPLICABILITY CRITERIA, EMISSION LIMITS, AND MANAGEMENT PRACTICES
FOR STORAGE TANKS
yshivers on PROD1PC62 with RULES2
If you own or operate
Then you must
1. A gasoline storage tank with a capacity of less than 75
cubic meters (m3).
Equip each gasoline storage tank with a fixed roof that is mounted to the storage
tank in a stationary manner, and maintain all openings in a closed position at all
times when not in use.
(a) Reduce emissions of total organic HAP or TOC by 95 weight-percent with a
closed vent system and control device as specified in § 60.112b(a)(3) of this chapter; or
2. A gasoline storage tank with a capacity of greater than
or equal to 75 m3.
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
PO 00000
Frm 00026
Fmt 4701
Sfmt 4700
E:\FR\FM\10JAR2.SGM
10JAR2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
1941
TABLE 1 TO SUBPART BBBBBB OF PART 63.—APPLICABILITY CRITERIA, EMISSION LIMITS, AND MANAGEMENT PRACTICES
FOR STORAGE TANKS—Continued
If you own or operate
Then you must
(b) Equip each internal floating roof gasoline storage tank according to the requirements in § 60.112b(a)(1) of this chapter, except for the secondary seal requirements under § 60.112b(a)(1)(ii)(B) and the requirements in § 60.112b(a)(1)(iv)
through (ix) of this chapter; and
(c) Equip each external floating roof gasoline storage tank according to the requirements in § 60.112b(a)(2) of this chapter, except that the requirements of
§ 60.112b(a)(2)(ii) of this chapter shall only be required if such storage tank does
not currently meet the requirements of § 60.112b(a)(2)(i) of this chapter; or
(d) Equip and operate each internal and external floating roof gasoline storage tank
according to the applicable requirements in § 63.1063(a)(1) and (b), and equip
each external floating roof gasoline storage tank according to the requirements of
§ 63.1063(a)(2) if such storage tank does not currently meet the requirements of
§ 63.1063(a)(1).
TABLE 2 TO SUBPART BBBBBB OF PART 63.—APPLICABILITY CRITERIA, EMISSION LIMITS, AND MANAGEMENT PRACTICES
FOR LOADING RACKS
If you own or operate
Then you must
1. A gasoline loading rack(s) at a bulk gasoline terminal
with a gasoline throughput of 250,000 gallons per day,
or greater.
(a) Equip your loading rack(s) with a vapor collection system designed to collect the
TOC vapors displaced from cargo tanks during product loading; and
(b) Reduce emissions of TOC to less than or equal to 80 mg/l of gasoline loaded into
gasoline cargo tanks at the loading rack; and
(c) Design and operate the vapor collection system to prevent any TOC vapors collected at one loading rack from passing to another loading rack; and
(d) Limit the loading of gasoline into gasoline cargo tanks that are vapor tight using
the procedures specified in § 60.502(e) through (j) of this chapter. For the purposes of this section, the term ‘‘tank truck’’ as used in § 60.502(e) through (j) of
this chapter means ‘‘cargo tank’’ as defined in § 63.11100.
(a) Use submerged filling with a submerged fill pipe that is no more than 6 inches
from the bottom of the cargo tank.
(b) Make records available within 24 hours of a request by the Administrator to document your gasoline throughput.
2. A gasoline loading rack(s) at a bulk gasoline terminal
with a gasoline throughput of less than 250,000 gallons
per day.
TABLE 3 TO SUBPART BBBBBB OF PART 63.—APPLICABILITY OF GENERAL PROVISIONS
Citation
Subject
Brief description
Applies to subpart
BBBBBB
§ 63.1 ...................................
Applicability ........................
Yes, specific requirements
given in § 63.11081.
§ 63.1(c)(2) ...........................
Title V permit .....................
Initial applicability determination; applicability after
standard established; permit requirements; extensions, notifications.
Requirements for obtaining a title V permit from the
applicable permitting authority.
§ 63.2 ...................................
Definitions ..........................
Definitions for part 63 standards ...................................
§ 63.3 ...................................
§ 63.4 ...................................
Units and Abbreviations ....
Prohibited Activities and
Circumvention.
Construction/Reconstruction.
Compliance with Standards/Operation & Maintenance Applicability.
Compliance Dates for New
and Reconstructed
Sources.
Notification .........................
Units and abbreviations for part 63 standards ..............
Prohibited activities; circumvention, severability ...........
Yes, § 63.11081(b) of subpart BBBBBB exempts
identified area sources
from the obligation to obtain title V operating permits.
Yes, additional definitions
in § 63.11100.
Yes.
Yes.
Applicability; applications; approvals .............................
Yes.
§ 63.5 ...................................
§ 63.6(a) ...............................
§ 63.6(b)(1)–(4) ....................
yshivers on PROD1PC62 with RULES2
§ 63.6(b)(5) ..........................
§ 63.6(b)(6) ..........................
§ 63.6(b)(7) ..........................
VerDate Aug<31>2005
14:31 Jan 09, 2008
[Reserved].
Compliance Dates for New
and Reconstructed Area
Sources that Become
Major.
Jkt 214001
PO 00000
General Provisions apply unless compliance exten- Yes.
sion; General Provisions apply to area sources that
become major.
Standards apply at effective date; 3 years after effec- Yes.
tive date; upon startup; 10 years after construction
or reconstruction commences for CAA section 112(f).
Must notify if commenced construction or reconstruc- Yes.
tion after proposal.
Area sources that become major must comply with
major source standards immediately upon becoming
major, regardless of whether required to comply
when they were an area source.
Frm 00027
Fmt 4701
Sfmt 4700
E:\FR\FM\10JAR2.SGM
10JAR2
No.
1942
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
TABLE 3 TO SUBPART BBBBBB OF PART 63.—APPLICABILITY OF GENERAL PROVISIONS—Continued
Citation
Subject
§ 63.6(c)(1)–(2) ....................
Compliance Dates for Existing Sources.
§ 63.6(c)(3)–(4) ....................
§ 63.6(c)(5) ...........................
[Reserved].
Compliance Dates for Existing Area Sources that
Become Major.
[Reserved].
Operation & Maintenance
§ 63.6(d) ...............................
§ 63.6(e)(1) ..........................
§ 63.6(e)(2) ..........................
§ 63.6(e)(3) ..........................
§ 63.6(f)(1) ...........................
§ 63.6(f)(2)–(3) .....................
§ 63.6(g)(1)–(3) ....................
§ 63.6(h)(1) ..........................
§ 63.6(h)(2)(i) .......................
§ 63.6(h)(2)(ii) ......................
§ 63.6(h)(2)(iii) ......................
§ 63.6(h)(3) ..........................
§ 63.6(h)(4) ..........................
§ 63.6(h)(5)(i), (iii)–(v) ..........
§ 63.6(h) (5)(ii) .....................
§ 63.6(h)(6) ..........................
§ 63.6(h)(7)(i) .......................
§ 63.6(h)(7)(ii) ......................
§ 63.6(h)(7)(iii) ......................
§ 63.6(h)(7)(iv) .....................
yshivers on PROD1PC62 with RULES2
§ 63.6(h)(7)(v) ......................
§ 63.6(h)(8) ..........................
VerDate Aug<31>2005
14:31 Jan 09, 2008
Applies to subpart
BBBBBB
Brief description
Comply according to date in this subpart, which must
be no later than 3 years after effective date; for
CAA section 112(f) standards, comply within 90
days of effective date unless compliance extension.
No, § 63.11083 specifies
the compliance dates.
Area sources that become major must comply with
major source standards by date indicated in this
subpart or by equivalent time period (e.g., 3 years).
No.
Operate to minimize emissions at all times; correct
malfunctions as soon as practicable; and operation
and maintenance requirements independently enforceable; information Administrator will use to determine if operation and maintenance requirements
were met.
Yes.
Requirement for SSM plan; content of SSM plan; actions during SSM.
You must comply with emission standards at all times
except during SSM.
Compliance based on performance test, operation and
maintenance plans, records, inspection.
Procedures for getting an alternative standard .............
You must comply with opacity/VE standards at all
times except during SSM.
If standard does not State test method, use EPA
Method 9 for opacity in appendix A of part 60 of this
chapter and EPA Method 22 for VE in appendix A
of part 60 of this chapter.
No.
Criteria for when previous opacity/VE testing can be
used to show compliance with this subpart.
No.
Must notify Administrator of anticipated date of observation.
Dates and schedule for conducting opacity/VE observations.
Must have at least 3 hours of observation with 30 6minute averages.
Must keep records available and allow Administrator
to inspect.
No.
Must submit COMS data with other performance test
data.
No.
Can submit COMS data instead of EPA Method 9 results even if rule requires EPA Method 9 in appendix A of part 60 of this chapter, but must notify Administrator before performance test.
Averaging Time for COMS To determine compliance, must reduce COMS data to
During Performance Test.
6-minute averages.
COMS Requirements ........ Owner/operator must demonstrate that COMS performance evaluations are conducted according to
§ 63.8(e); COMS are properly maintained and operated according to § 63.8(c) and data quality as
§ 63.8(d).
Determining Compliance
COMS is probable but not conclusive evidence of
with Opacity/VE Standcompliance with opacity standard, even if EPA
ards.
Method 9 observation shows otherwise. Requirements for COMS to be probable evidence-proper
maintenance, meeting Performance Specification 1
in appendix B of part 60 of this chapter, and data
have not been altered.
Determining Compliance
Administrator will use all COMS, EPA Method 9 (in
with Opacity/VE Standappendix A of part 60 of this chapter), and EPA
ards.
Method 22 (in appendix A of part 60 of this chapter)
results, as well as information about operation and
maintenance to determine compliance.
No.
[Reserved].
Startup, Shutdown, and
Malfunction (SSM) plan.
Compliance Except During
SSM.
Methods for Determining
Compliance.
Alternative Standard ..........
Compliance with Opacity/
VE Standards.
Determining Compliance
with Opacity/VE Standards.
[Reserved].
Using Previous Tests to
Demonstrate Compliance with Opacity/VE
Standards.
[Reserved].
Notification of Opacity/VE
Observation Date.
Conducting Opacity/VE
Observations.
Opacity Test Duration and
Averaging Times.
Records of Conditions During Opacity/VE Observations.
Report Continuous Opacity
Monitoring System
(COMS) Monitoring Data
from Performance Test.
Using COMS Instead of
EPA Method 9.
Jkt 214001
PO 00000
Frm 00028
Fmt 4701
Sfmt 4700
E:\FR\FM\10JAR2.SGM
10JAR2
No.
Yes.
Yes.
No.
No.
No.
No.
No.
No.
No.
No.
No.
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
1943
TABLE 3 TO SUBPART BBBBBB OF PART 63.—APPLICABILITY OF GENERAL PROVISIONS—Continued
Applies to subpart
BBBBBB
Subject
Brief description
§ 63.6(h)(9) ..........................
Adjusted Opacity Standard
§ 63.6(i)(1)–(14) ...................
Compliance Extension .......
§ 63.6(j) ................................
§ 63.7(a)(2) ..........................
Presidential Compliance
Exemption.
Performance Test Dates ...
§ 63.7(a)(3) ..........................
Section 114 Authority ........
§ 63.7(b)(1) ..........................
Notification of Performance
Test.
Notification of Re-scheduling.
Procedures for Administrator to adjust an opacity
standard.
Procedures and criteria for Administrator to grant compliance extension.
President may exempt any source from requirement to
comply with this subpart.
Dates for conducting initial performance testing; must
conduct 180 days after compliance date.
Administrator may require a performance test under
CAA section 114 at any time.
Must notify Administrator 60 days before the test ........
§ 63.7(b)(2) ..........................
§ 63.7(c) ...............................
Quality Assurance (QA)/
Test Plan.
§ 63.7(d) ...............................
§ 63.7(e)(1) ..........................
Testing Facilities ................
Conditions for Conducting
Performance Tests.
§ 63.7(e)(2) ..........................
§ 63.7(e)(3) ..........................
Conditions for Conducting
Performance Tests.
Test Run Duration .............
§ 63.7(f) ................................
Alternative Test Method ....
§ 63.7(g) ...............................
Performance Test Data
Analysis.
§ 63.7(h) ...............................
Waiver of Tests .................
§ 63.8(a)(1) ..........................
§ 63.8(a)(2) ..........................
Applicability of Monitoring
Requirements.
Performance Specifications
§ 63.8(a)(3) ..........................
§ 63.8(a)(4) ..........................
§ 63.8(b)(1) ..........................
[Reserved].
Monitoring of Flares ..........
Monitoring ..........................
§ 63.8(b)(2)–(3) ....................
Multiple Effluents and Multiple Monitoring Systems.
§ 63.8(c)(1) ...........................
§ 63.8(c)(1)(i)–(iii) .................
Monitoring System Operation and Maintenance.
Routine and Predictable
SSM.
§ 63.8(c) (2)–(8) ...................
yshivers on PROD1PC62 with RULES2
Citation
CMS Requirements ...........
§ 63.8(d) ...............................
CMS Quality Control .........
§ 63.8(e) ...............................
CMS Performance Evaluation.
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
PO 00000
If have to reschedule performance test, must notify
Administrator of rescheduled date as soon as practicable and without delay.
Requirement to submit site-specific test plan 60 days
before the test or on date Administrator agrees with;
test plan approval procedures; performance audit
requirements; internal and external QA procedures
for testing.
Requirements for testing facilities .................................
Performance tests must be conducted under representative conditions; cannot conduct performance
tests during SSM.
Must conduct according to this subpart and EPA test
methods unless Administrator approves alternative.
Must have three test runs of at least 1 hour each;
compliance is based on arithmetic mean of three
runs; conditions when data from an additional test
run can be used.
Procedures by which Administrator can grant approval
to use an intermediate or major change, or alternative to a test method.
Must include raw data in performance test report;
must submit performance test data 60 days after
end of test with the notification of compliance status;
keep data for 5 years.
Procedures for Administrator to waive performance
test.
Subject to all monitoring requirements in standard ......
No.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Performance specifications in appendix B of 40 CFR
part 60 apply.
Yes.
Monitoring requirements for flares in § 63.11 apply ......
Must conduct monitoring according to standard unless
Administrator approves alternative.
Specific requirements for installing monitoring systems; must install on each affected source or after
combined with another affected source before it is
released to the atmosphere provided the monitoring
is sufficient to demonstrate compliance with the
standard; if more than one monitoring system on an
emission point, must report all monitoring system results, unless one monitoring system is a backup.
Maintain monitoring system in a manner consistent
with good air pollution control practices.
Follow the SSM plan for routine repairs; keep parts for
routine repairs readily available; reporting requirements for SSM when action is described in SSM
plan.
Must install to get representative emission or parameter measurements; must verify operational status
before or at performance test.
Requirements for CMS quality control, including calibration, etc.; must keep quality control plan on
record for 5 years; keep old versions for 5 years
after revisions.
Notification, performance evaluation test plan, reports
Yes.
Yes.
Frm 00029
Fmt 4701
Sfmt 4700
E:\FR\FM\10JAR2.SGM
10JAR2
Yes.
Yes.
Yes.
Yes.
No.
Yes.
1944
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
TABLE 3 TO SUBPART BBBBBB OF PART 63.—APPLICABILITY OF GENERAL PROVISIONS—Continued
Applies to subpart
BBBBBB
Citation
Subject
Brief description
§ 63.8(f) (1)–(5) ....................
§ 63.8(g) ...............................
Alternative Monitoring
Method.
Alternative to Relative Accuracy Test.
Data Reduction ..................
§ 63.9(a) ...............................
§ 63.9(b) (1)–(2), (4)–(5) ......
Notification Requirements
Initial Notifications .............
§ 63.9(c) ...............................
Request for Compliance
Extension.
§ 63.9(d) ...............................
Notification of Special
Compliance Requirements for New Sources.
Notification of Performance
Test.
Notification of VE/Opacity
Test.
Additional Notifications
When Using CMS.
Procedures for Administrator to approve alternative
monitoring.
Procedures for Administrator to approve alternative
relative accuracy tests for CEMS.
COMS 6-minute averages calculated over at least 36
evenly spaced data points; CEMS 1 hour averages
computed over at least 4 equally spaced data
points; data that cannot be used in average.
Applicability and State delegation .................................
Submit notification within 120 days after effective date;
notification of intent to construct/reconstruct, notification of commencement of construction/reconstruction, notification of startup; contents of each.
Can request if cannot comply by date or if installed
best available control technology or lowest achievable emission rate.
For sources that commence construction between proposal and promulgation and want to comply 3 years
after effective date.
Notify Administrator 60 days prior .................................
§ 63.8(f)(6) ...........................
§ 63.9(e) ...............................
§ 63.9(f) ................................
§ 63.9(g) ...............................
§ 63.9(h) (1)–(6) ...................
Notification of Compliance
Status.
§ 63.9(i) ................................
§ 63.10(a) .............................
Adjustment of Submittal
Deadlines.
Change in Previous Information.
Record-keeping/Reporting
§ 63.10(b)(1) ........................
Record-keeping/Reporting
§ 63.10(b)(2)(i)–(iv) ..............
Records Related to SSM ..
§ 63.10(b)(2)(vi)–(xi) ............
§ 63.10(b)(2)(xii) ...................
§ 63.10(b)(2)(xiii) ..................
CMS Records ....................
Records .............................
Records .............................
§ 63.10(b)(2)(xiv) ..................
Records .............................
§ 63.10(b)(3) ........................
§ 63.10(c) .............................
§ 63.10(d)(1) ........................
§ 63.10(d)(4) ........................
Records .............................
Records .............................
General Reporting Requirements.
Report of Performance
Test Results.
Reporting Opacity or VE
Observations.
Progress Reports ..............
§ 63.10(d)(5) ........................
§ 63.10(e)(1)–(2) ..................
SSM Reports .....................
Additional CMS Reports ....
§ 63.10(e)(3)(i)–(iii) ..............
Reports ..............................
§ 63.9(j) ................................
§ 63.10(d)(2) ........................
yshivers on PROD1PC62 with RULES2
§ 63.10(d)(3) ........................
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
PO 00000
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Notify Administrator 30 days prior .................................
No.
Notification of performance evaluation; notification
about use of COMS data; notification that exceeded
criterion for relative accuracy alternative.
Contents due 60 days after end of performance test or
other compliance demonstration, except for opacity/
VE, which are due 30 days after; when to submit to
Federal vs. State authority.
Procedures for Administrator to approve change when
notifications must be submitted.
Must submit within 15 days after the change ...............
Yes, however, there are no
opacity standards.
Applies to all, unless compliance extension; when to
submit to Federal vs. State authority; procedures for
owners of more than one source.
General requirements; keep all records readily available; keep for 5 years.
Occurrence of each for operations (process equipment); occurrence of each malfunction of air pollution control equipment; maintenance on air pollution
control equipment; actions during SSM.
Malfunctions, inoperative, out-of-control periods ..........
Records when under waiver .........................................
Records when using alternative to relative accuracy
test.
All documentation supporting initial notification and notification of compliance status.
Applicability determinations ...........................................
Additional records for CMS ...........................................
Requirement to report ...................................................
Yes.
Yes, however, there are no
opacity standards.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
No.
Yes.
When to submit to Federal or State authority ...............
Yes.
What to report and when ..............................................
No.
Must submit progress reports on schedule if under
compliance extension.
Contents and submission ..............................................
Must report results for each CEMS on a unit; written
copy of CMS performance evaluation; 2–3 copies of
COMS performance evaluation.
Schedule for reporting excess emissions .....................
Yes.
Frm 00030
Fmt 4701
Sfmt 4700
E:\FR\FM\10JAR2.SGM
10JAR2
Yes.
No.
Yes, note that § 63.11095
specifies excess emission events for this subpart.
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
1945
TABLE 3 TO SUBPART BBBBBB OF PART 63.—APPLICABILITY OF GENERAL PROVISIONS—Continued
Citation
Subject
Brief description
Applies to subpart
BBBBBB
§ 63.10(e)(3)(iv)–(v) .............
Excess Emissions Reports
Yes, § 63.11095 specifies
excess emission events
for this subpart.
§ 63.10(e)(3)(vi)–(viii) ...........
Excess Emissions Report
and Summary Report.
§ 63.10(e)(4) ........................
§ 63.10(f) ..............................
§ 63.11(b) .............................
Reporting COMS Data ......
Waiver for Recordkeeping/
Reporting.
Flares .................................
Requirement to revert to quarterly submission if there
is an excess emissions and parameter monitor
exceedances (now defined as deviations); provision
to request semiannual reporting after compliance for
1 year; submit report by 30th day following end of
quarter or calendar half; if there has not been an
exceedance or excess emissions (now defined as
deviations), report contents in a statement that there
have been no deviations; must submit report containing all of the information in §§ 63.8(c)(7)–(8) and
63.10(c)(5)–(13).
Requirements for reporting excess emissions for CMS;
requires all of the information in §§ 63.8(c)(7)–(8)
and 63.10(c)(5)–(13).
Must submit COMS data with performance test data ...
Procedures for Administrator to waive ..........................
§ 63.12 .................................
§ 63.13 .................................
Delegation .........................
Addresses ..........................
§ 63.14 .................................
Incorporations by Reference.
Availability of Information ..
§ 63.15 .................................
4. Part 63 is amended by adding a new
subpart CCCCCC to read as follows:
I
Subpart CCCCCC—National Emission
Standards for Hazardous Air Pollutants
for Source Category: Gasoline
Dispensing Facilities
Sec.
What This Subpart Covers
63.11110 What is the purpose of this
subpart?
63.11111 Am I subject to the requirements
in this subpart?
63.11112 What parts of my affected source
does this subpart cover?
63.11113 When do I have to comply with
this subpart?
Emission Limitations and Management
Practices
63.11116 Requirements for facilities with
monthly throughput of less than 10,000
gallons of gasoline.
63.11117 Requirements for facilities with
monthly throughput of 10,000 gallons of
gasoline or more.
63.11118 Requirements for facilities with
monthly throughput of 100,000 gallons
of gasoline or more.
yshivers on PROD1PC62 with RULES2
Testing and Monitoring Requirements
63.11120 What testing and monitoring
requirements must I meet?
Notification, Records, and Reports
63.11124 What notifications must I submit
and when?
63.11125 What are my recordkeeping
requirements?
63.11126 What are my reporting
requirements?
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
Requirements for flares .................................................
State authority to enforce standards .............................
Addresses where reports, notifications, and requests
are sent.
Test methods incorporated by reference ......................
Public and confidential information ...............................
Other Requirements and Information
63.11130 What parts of the General
Provisions apply to me?
63.11131 Who implements and enforces
this subpart?
63.11132 What definitions apply to this
subpart?
Tables to Subpart CCCCCC of Part 63
Table 1 to Subpart CCCCCC of Part 63—
Applicability Criteria and Management
Practices for Gasoline Dispensing
Facilities with Monthly Throughput of
100,000 Gallons of Gasoline or More
Table 2 to Subpart CCCCCC of Part 63—
Applicability Criteria and Management
Practices for Gasoline Cargo Tanks
Unloading at Gasoline Dispensing
Facilities with Monthly Throughput of
100,000 Gallons of Gasoline or More
Table 3 to Subpart CCCCCC of Part 63—
Applicability of General Provisions
Subpart CCCCCC—National Emission
Standards for Hazardous Air Pollutants
for Source Category: Gasoline
Dispensing Facilities
What This Subpart Covers
§ 63.11110
subpart?
What is the purpose of this
This subpart establishes national
emission limitations and management
practices for hazardous air pollutants
(HAP) emitted from the loading of
gasoline storage tanks at gasoline
dispensing facilities (GDF). This subpart
also establishes requirements to
demonstrate compliance with the
emission limitations and management
practices.
PO 00000
Frm 00031
Fmt 4701
Sfmt 4700
Yes.
Yes.
Yes.
Yes, the section references
§ 63.11(b).
Yes.
Yes.
Yes.
Yes.
§ 63.11111 Am I subject to the
requirements in this subpart?
(a) The affected source to which this
subpart applies is each GDF that is
located at an area source. The affected
source includes each gasoline cargo tank
during the delivery of product to a GDF
and also includes each storage tank.
(b) If your GDF has a monthly
throughput of less than 10,000 gallons
of gasoline, you must comply with the
requirements in § 63.11116.
(c) If your GDF has a monthly
throughput of 10,000 gallons of gasoline
or more, you must comply with the
requirements in § 63.11117.
(d) If your GDF has a monthly
throughput of 100,000 gallons of
gasoline or more, you must comply with
the requirements in § 63.11118.
(e) An affected source shall, upon
request by the Administrator,
demonstrate that their average monthly
throughput is less than the 10,000gallon or the 100,000-gallon threshold
level, as applicable.
(f) If you are an owner or operator of
affected sources, as defined in
paragraph (a) of this section, you are not
required to obtain a permit under 40
CFR part 70 or 40 CFR part 71 as a result
of being subject to this subpart.
However, you must still apply for and
obtain a permit under 40 CFR part 70 or
40 CFR part 71 if you meet one or more
of the applicability criteria found in 40
CFR 70.3(a) and (b) or 40 CFR 71.3(a)
and (b).
E:\FR\FM\10JAR2.SGM
10JAR2
1946
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
(g) The loading of aviation gasoline
storage tanks at airports is not subject to
this subpart and the aviation gasoline is
not included in the gasoline throughput
specified in paragraphs (b) through (e)
of this section.
§ 63.11112 What parts of my affected
source does this subpart cover?
(a) The emission sources to which this
subpart applies are gasoline storage
tanks and associated equipment
components in vapor or liquid gasoline
service at new, reconstructed, or
existing GDF that meet the criteria
specified in § 63.11111. Pressure/
Vacuum vents on gasoline storage tanks
and the equipment necessary to unload
product from cargo tanks into the
storage tanks at GDF are covered
emission sources. The equipment used
for the refueling of motor vehicles is not
covered by this subpart.
(b) An affected source is a new
affected source if you commenced
construction on the affected source after
November 9, 2006, and you meet the
applicability criteria in § 63.11111 at the
time you commenced operation.
(c) An affected source is reconstructed
if you meet the criteria for
reconstruction as defined in § 63.2.
(d) An affected source is an existing
affected source if it is not new or
reconstructed.
yshivers on PROD1PC62 with RULES2
§ 63.11113 When do I have to comply with
this subpart?
(a) If you have a new or reconstructed
affected source, you must comply with
this subpart according to paragraphs
(a)(1) and (2) of this section.
(1) If you start up your affected source
before January 10, 2008, you must
comply with the standards in this
subpart no later than January 10, 2008.
(2) If you start up your affected source
after January 10, 2008, you must comply
with the standards in this subpart upon
startup of your affected source.
(b) If you have an existing affected
source, you must comply with the
standards in this subpart no later than
January 10, 2011.
(c) If you have an existing affected
source that becomes subject to the
control requirements in this subpart
because of an increase in the average
monthly throughput, as specified in
§ 63.11111(c) or § 63.11111(d), you must
comply with the standards in this
subpart no later than 3 years after the
affected source becomes subject to the
control requirements in this subpart.
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
Emission Limitations and Management
Practices
§ 63.11118 Requirements for facilities with
monthly throughput of 100,000 gallons of
gasoline or more.
§ 63.11116 Requirements for facilities with
monthly throughput of less than 10,000
gallons of gasoline.
(a) You must comply with the
requirements in §§ 63.11116(a) and
63.11117(b).
(b) Except as provided in paragraph
(c) of this section, you must meet the
requirements in either paragraph (b)(1)
or paragraph (b)(2) of this section.
(1) Each management practice in
Table 1 to this subpart that applies to
your GDF.
(2) If, prior to January 10, 2008, you
satisfy the requirements in both
paragraphs (b)(2)(i) and (ii) of this
section, you will be deemed in
compliance with this subsection.
(i) You operate a vapor balance
system at your GDF that meets the
requirements of either paragraph
(b)(2)(i)(A) or paragraph (b)(2)(i)(B) of
this section.
(A) Achieves emissions reduction of
at least 90 percent.
(B) Operates using management
practices at least as stringent as those in
Table 1 to this subpart.
(ii) Your gasoline dispensing facility
is in compliance with an enforceable
State, local, or tribal rule or permit that
contains requirements of either
paragraph (b)(2)(i)(A) or paragraph
(b)(2)(i)(B) of this section.
(c) The emission sources listed in
paragraphs (c)(1) through (3) of this
section are not required to comply with
the control requirements in paragraphs
(a) and (b) of this section, but must
comply with the requirements in
§ 63.11116.
(1) Gasoline storage tanks with a
capacity of less than 250 gallons that are
constructed after January 10, 2008.
(2) Gasoline storage tanks with a
capacity of less than 2,000 gallons that
were constructed before January 10,
2008.
(3) Gasoline storage tanks equipped
with floating roofs, or the equivalent.
(d) Cargo tanks unloading at GDF
must comply with the management
practices in Table 2 to this subpart.
(e) You must comply with the
applicable testing requirements
contained in § 63.11120.
(f) You must submit the applicable
notifications as required under
§ 63.11124.
(g) You must keep records and submit
reports as specified in §§ 63.11125 and
63.11126.
(h) You must comply with the
requirements of this subpart by the
applicable dates contained in
§ 63.11113.
(a) You must not allow gasoline to be
handled in a manner that would result
in vapor releases to the atmosphere for
extended periods of time. Measures to
be taken include, but are not limited to,
the following:
(1) Minimize gasoline spills;
(2) Clean up spills as expeditiously as
practicable;
(3) Cover all open gasoline containers
and all gasoline storage tank fill-pipes
with a gasketed seal when not in use;
(4) Minimize gasoline sent to open
waste collection systems that collect
and transport gasoline to reclamation
and recycling devices, such as oil/water
separators.
(b) You are not required to submit
notifications or reports, but you must
have records available within 24 hours
of a request by the Administrator to
document your gasoline throughput.
(c) You must comply with the
requirements of this subpart by the
applicable dates specified in § 63.11113.
§ 63.11117 Requirements for facilities with
monthly throughput of 10,000 gallons of
gasoline or more.
(a) You must comply with the
requirements in section § 63.11116(a).
(b) Except as specified in paragraph
(c), you must only load gasoline into
storage tanks at your facility by utilizing
submerged filling, as defined in
§ 63.11132, and as specified in
paragraph (b)(1) or paragraph (b)(2) of
this section.
(1) Submerged fill pipes installed on
or before November 9, 2006, must be no
more than 12 inches from the bottom of
the storage tank.
(2) Submerged fill pipes installed after
November 9, 2006, must be no more
than 6 inches from the bottom of the
storage tank.
(c) Gasoline storage tanks with a
capacity of less than 250 gallons are not
required to comply with the submerged
fill requirements in paragraph (b) of this
section, but must comply only with all
of the requirements in § 63.11116.
(d) You must have records available
within 24 hours of a request by the
Administrator to document your
gasoline throughput.
(e) You must submit the applicable
notifications as required under
§ 63.11124(b).
(f) You must comply with the
requirements of this subpart by the
applicable dates contained in
§ 63.11113.
PO 00000
Frm 00032
Fmt 4701
Sfmt 4700
E:\FR\FM\10JAR2.SGM
10JAR2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
Testing and Monitoring Requirements
yshivers on PROD1PC62 with RULES2
§ 63.11120 What testing and monitoring
requirements must I meet?
(a) Each owner or operator, at the time
of installation of a vapor balance system
required under § 63.11118(b)(1), and
every 3 years thereafter, must comply
with the requirements in paragraphs
(a)(1) and (2) of this section.
(1) You must demonstrate compliance
with the leak rate and cracking pressure
requirements, specified in item 1(g) of
Table 1 to this subpart, for pressurevacuum vent valves installed on your
gasoline storage tanks using the test
methods identified in paragraph (a)(1)(i)
or paragraph (a)(1)(ii) of this section.
(i) California Air Resources Board
Vapor Recovery Test Procedure TP–
201.1E,—Leak Rate and Cracking
Pressure of Pressure/Vacuum Vent
Valves, adopted October 8, 2003
(incorporated by reference, see § 63.14).
(ii) Use alternative test methods and
procedures in accordance with the
alternative test method requirements in
§ 63.7(f).
(2) You must demonstrate compliance
with the static pressure performance
requirement, specified in item 1(h) of
Table 1 to this subpart, for your vapor
balance system by conducting a static
pressure test on your gasoline storage
tanks using the test methods identified
in paragraph (a)(2)(i) or paragraph
(a)(2)(ii) of this section.
(i) California Air Resources Board
Vapor Recovery Test Procedure TP–
201.3,—Determination of 2-Inch WC
Static Pressure Performance of Vapor
Recovery Systems of Dispensing
Facilities, adopted April 12, 1996, and
amended March 17, 1999 (incorporated
by reference, see § 63.14).
(ii) Use alternative test methods and
procedures in accordance with the
alternative test method requirements in
§ 63.7(f).
(b) Each owner or operator choosing,
under the provisions of § 63.6(g), to use
a vapor balance system other than that
described in Table 1 to this subpart
must demonstrate to the Administrator
or delegated authority under paragraph
§ 63.11131(a) of this subpart, the
equivalency of their vapor balance
system to that described in Table 1 to
this subpart using the procedures
specified in paragraphs (b)(1) through
(3) of this section.
(1) You must demonstrate initial
compliance by conducting an initial
performance test on the vapor balance
system to demonstrate that the vapor
balance system achieves 95 percent
reduction using the California Air
Resources Board Vapor Recovery Test
Procedure TP–201.1,—Volumetric
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
Efficiency for Phase I Vapor Recovery
Systems, adopted April 12, 1996, and
amended February 1, 2001, and October
8, 2003, (incorporated by reference, see
§ 63.14).
(2) You must, during the initial
performance test required under
paragraph (b)(1) of this section,
determine and document alternative
acceptable values for the leak rate and
cracking pressure requirements
specified in item 1(g) of Table 1 to this
subpart and for the static pressure
performance requirement in item 1(h) of
Table 1 to this subpart.
(3) You must comply with the testing
requirements specified in paragraph (a)
of this section.
Notifications, Records, and Reports
§ 63.11124 What notifications must I
submit and when?
(a) Each owner or operator subject to
the control requirements in § 63.11117
must comply with paragraphs (a)(1)
through (4) of this section.
(1) You must submit an Initial
Notification that you are subject to this
subpart by May 9, 2008, or at the time
you become subject to the control
requirements in § 63.11117, unless you
meet the requirements in paragraph
(a)(3) of this section. The Initial
Notification must contain the
information specified in paragraphs
(a)(1)(i) through (iii) of this section. The
notification must be submitted to the
applicable EPA Regional Office and
delegated State authority as specified in
§ 63.13.
(i) The name and address of the owner
and the operator.
(ii) The address (i.e., physical
location) of the GDF.
(iii) A statement that the notification
is being submitted in response to this
subpart and identifying the
requirements in paragraphs (a), (b), and
(c)(1) or paragraph (c)(2) of § 63.11117
that apply to you.
(2) You must submit a Notification of
Compliance Status to the applicable
EPA Regional Office and the delegated
State authority, as specified in § 63.13,
by the compliance date specified in
§ 63.11113 unless you meet the
requirements in paragraph (a)(3) of this
section. The Notification of Compliance
Status must be signed by a responsible
official who must certify its accuracy
and must indicate whether the source
has complied with the requirements of
this subpart. If your facility is in
compliance with the requirements of
this subpart at the time the Initial
Notification required under paragraph
(a)(1) of this section is due, the
Notification of Compliance Status may
PO 00000
Frm 00033
Fmt 4701
Sfmt 4700
1947
be submitted in lieu of the Initial
Notification provided it contains the
information required under paragraph
(a)(1) of this section.
(3) If, prior to January 10, 2008, you
are operating in compliance with an
enforceable State, local, or tribal rule or
permit that requires submerged fill as
specified in § 63.11117(b), you are not
required to submit an Initial
Notification or a Notification of
Compliance Status under paragraph
(a)(1) or paragraph (a)(2) of this section.
(b) Each owner or operator subject to
the control requirements in § 63.11118
must comply with paragraphs (b)(1)
through (5) of this section.
(1) You must submit an Initial
Notification that you are subject to this
subpart by May 9, 2008, or at the time
you become subject to the control
requirements in § 63.11118. The Initial
Notification must contain the
information specified in paragraphs
(b)(1)(i) through (iii) of this section. The
notification must be submitted to the
applicable EPA Regional Office and the
delegated State authority as specified in
§ 63.13.
(i) The name and address of the owner
and the operator.
(ii) The address (i.e., physical
location) of the GDF.
(iii) A statement that the notification
is being submitted in response to this
subpart and identifying the
requirements in paragraphs (a) through
(d) of § 63.11118 that apply to you.
(2) You must submit a Notification of
Compliance Status to the applicable
EPA Regional Office and the delegated
State authority, as specified in § 63.13,
by the compliance date specified in
§ 63.11113. The Notification of
Compliance Status must be signed by a
responsible official who must certify its
accuracy and must indicate whether the
source has complied with the
requirements of this subpart. If your
facility is in compliance with the
requirements of this subpart at the time
the Initial Notification required under
paragraph (b)(1) of this section is due,
the Notification of Compliance Status
may be submitted in lieu of the Initial
Notification provided it contains the
information required under paragraph
(b)(1) of this section.
(3) If, prior to January 10, 2008, you
satisfy the requirements in both
paragraphs (b)(3)(i) and (ii) of this
section, you are not required to submit
an Initial Notification or a Notification
of Compliance Status under paragraph
(b)(1) or paragraph (b)(2) of this
subsection.
(i) You operate a vapor balance
system at your gasoline dispensing
facility that meets the requirements of
E:\FR\FM\10JAR2.SGM
10JAR2
1948
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
either paragraphs (b)(3)(i)(A) or
(b)(3)(i)(B) of this section.
(A) Achieves emissions reduction of
at least 90 percent.
(B) Operates using management
practices at least as stringent as those in
Table 1 to this subpart.
(ii) Your gasoline dispensing facility
is in compliance with an enforceable
State, local, or tribal rule or permit that
contains requirements of either
paragraphs (b)(3)(i)(A) or (b)(3)(i)(B) of
this section.
(4) You must submit a Notification of
Performance Test, as specified in
§ 63.9(e), prior to initiating testing
required by § 63.11120(a) and (b).
(5) You must submit additional
notifications specified in § 63.9, as
applicable.
§ 63.11125 What are my recordkeeping
requirements?
(a) Each owner or operator subject to
the management practices in § 63.11118
must keep records of all tests performed
under § 63.11120(a) and (b).
(b) Records required under paragraph
(a) of this section shall be kept for a
period of 5 years and shall be made
available for inspection by the
Administrator’s delegated
representatives during the course of a
site visit.
§ 63.11126 What are my reporting
requirements?
Each owner or operator subject to the
management practices in § 63.11118
shall report to the Administrator the
results of all volumetric efficiency tests
required under § 63.11120(b). Reports
submitted under this paragraph must be
submitted within 180 days of the
completion of the performance testing.
Other Requirements and Information
§ 63.11130 What parts of the General
Provisions apply to me?
Table 3 to this subpart shows which
parts of the General Provisions apply to
you.
§ 63.11131 Who implements and enforces
this subpart?
(a) This subpart can be implemented
and enforced by the U.S. EPA or a
delegated authority such as the
applicable State, local, or tribal agency.
If the U.S. EPA Administrator has
delegated authority to a State, local, or
tribal agency, then that agency, in
addition to the U.S. EPA, has the
authority to implement and enforce this
subpart. Contact the applicable U.S.
EPA Regional Office to find out if
implementation and enforcement of this
subpart is delegated to a State, local, or
tribal agency.
(b) In delegating implementation and
enforcement authority of this subpart to
a State, local, or tribal agency under
subpart E of this part, the authorities
contained in paragraph (c) of this
section are retained by the
Administrator of U.S. EPA and cannot
be transferred to the State, local, or
tribal agency.
(c) The authorities that cannot be
delegated to State, local, or tribal
agencies are as specified in paragraphs
(c)(1) through (3) of this section.
(1) Approval of alternatives to the
requirements in §§ 63.11116 through
63.11118 and 63.11120.
(2) Approval of major alternatives to
test methods under § 63.7(e)(2)(ii) and
(f), as defined in § 63.90, and as required
in this subpart.
(3) Approval of major alternatives to
recordkeeping and reporting under
§ 63.10(f), as defined in § 63.90, and as
required in this subpart.
§ 63.11132
subpart?
What definitions apply to this
As used in this subpart, all terms not
defined herein shall have the meaning
given them in the Clean Air Act (CAA),
or in subparts A and BBBBBB of this
part. For purposes of this subpart,
definitions in this section supersede
definitions in other parts or subparts.
Dual-point vapor balance system
means a type of vapor balance system in
which the storage tank is equipped with
an entry port for a gasoline fill pipe and
a separate exit port for a vapor
connection.
Gasoline cargo tank means a delivery
tank truck or railcar which is loading
gasoline or which has loaded gasoline
on the immediately previous load.
Gasoline dispensing facility (GDF)
means any stationary facility which
dispenses gasoline into the fuel tank of
a motor vehicle.
Monthly throughput means the total
volume of gasoline that is loaded into
all gasoline storage tanks during a
month, as calculated on a rolling 30-day
average.
Submerged filling means, for the
purposes of this subpart, the filling of a
gasoline storage tank through a
submerged fill pipe whose discharge is
no more than the applicable distance
specified in § 63.11117(b) from the
bottom of the tank. Bottom filling of
gasoline storage tanks is included in this
definition.
Vapor balance system means a
combination of pipes and hoses that
create a closed system between the
vapor spaces of an unloading gasoline
cargo tank and a receiving storage tank
such that vapors displaced from the
storage tank are transferred to the
gasoline cargo tank being unloaded.
Vapor-tight means equipment that
allows no loss of vapors. Compliance
with vapor-tight requirements can be
determined by checking to ensure that
the concentration at a potential leak
source is not equal to or greater than 100
percent of the Lower Explosive Limit
when measured with a combustible gas
detector, calibrated with propane, at a
distance of 1 inch from the source.
TABLE 1 TO SUBPART CCCCCC OF PART 63.—APPLICABILITY CRITERIA AND MANAGEMENT PRACTICES FOR GASOLINE
DISPENSING FACILITIES WITH MONTHLY THROUGHPUT OF 100,000 GALLONS OF GASOLINE OR MORE
Then you must
1. A new, reconstructed, or existing GDF subject to
§ 63.11118.
yshivers on PROD1PC62 with RULES2
If you own or operate
Install and operate a vapor balance system on your gasoline storage tanks that
meets the design criteria in paragraphs (a) through (h).
(a) All vapor connections and lines on the storage tank shall be equipped with closures that seal upon disconnect.
(b) The vapor line from the gasoline storage tank to the gasoline cargo tank shall be
vapor-tight, as defined in § 63.11132.
(c) The vapor balance system shall be designed such that the pressure in the tank
truck does not exceed 18 inches water pressure or 5.9 inches water vacuum during product transfer.
(d) The vapor recovery and product adaptors, and the method of connection with the
delivery elbow, shall be designed so as to prevent the over-tightening or loosening
of fittings during normal delivery operations.
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
PO 00000
Frm 00034
Fmt 4701
Sfmt 4700
E:\FR\FM\10JAR2.SGM
10JAR2
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
1949
TABLE 1 TO SUBPART CCCCCC OF PART 63.—APPLICABILITY CRITERIA AND MANAGEMENT PRACTICES FOR GASOLINE
DISPENSING FACILITIES WITH MONTHLY THROUGHPUT OF 100,000 GALLONS OF GASOLINE OR MORE—Continued
If you own or operate
Then you must
2. For new or reconstructed GDF, or new storage tank(s)
at an existing affected facility subject to § 63.11118.
(e) If a gauge well separate from the fill tube is used, it shall be provided with a submerged drop tube that extends the same distance from the bottom of the storage
tank as specified in § 63.11117(b).
(f) Liquid fill connections for all systems shall be equipped with vapor-tight caps.
(g) Pressure/vacuum vent valves shall be installed on the storage tank vent pipes.
For systems where vapors from vehicle refueling operations are not recovered, the
positive cracking pressure shall be 13.8 inches of water and the negative cracking
pressure shall be 6.9 inches of water. For systems where vapors from vehicle refueling operations are recovered (Stage II controls), the positive cracking pressure
shall be 3 inches of water and the negative cracking pressure shall be 8 inches of
water. Deviations of within ± 0.5 inches of the specified positive cracking pressures
and ± 2.0 inches of the negative pressure are acceptable. The leak rates for pressure/vacuum valves, including connections, shall be less that or equal to 0.17
cubic foot per hour at a pressure of 2.0 inches of water and 0.21 cubic foot per
hour at a vacuum of 4 inches of water.
(h) The vapor balance system shall be capable of meeting the static pressure performance requirement of the following equation:
Pf = 2e¥500.887/v
Where:
Pf = Minimum allowable final pressure, inches of water.
v = Total ullage affected by the test, gallons.
e = Dimensionless constant equal to approximately 2.718.
2 = The initial pressure, inches water.
Equip your gasoline storage tanks with a dual-point vapor balance system, as defined in § 63.11132, and comply with the requirements of item 1 in this Table.
TABLE 2 TO SUBPART CCCCCC OF PART 63.—APPLICABILITY CRITERIA AND MANAGEMENT PRACTICES FOR GASOLINE
CARGO TANKS UNLOADING AT GASOLINE DISPENSING FACILITIES WITH MONTHLY THROUGHPUT OF 100,000 GALLONS OF GASOLINE OR MORE
If you own or operate
Then you must
A gasoline cargo tank .....................
Not unload gasoline into a storage tank at a GDF subject to the control requirements in this subpart unless
the following conditions are met:
(i) All hoses in the vapor balance system are properly connected,
(ii) The adapters or couplers that attach to the vapor line on the storage tank have closures that seal upon
disconnect,
(iii) All vapor return hoses, couplers, and adapters used in the gasoline delivery are vapor-tight,
(iv) All tank truck vapor return equipment is compatible in size and forms a vapor-tight connection with the
vapor balance equipment on the GDF storage tank, and
(v) All hatches on the tank truck are closed and securely fastened.
(vi) The filling of storage tanks at GDF shall be limited to unloading by vapor-tight gasoline cargo tanks.
Documentation that the cargo tank has met the specifications of EPA Method 27 shall be carried on the
cargo tank.
TABLE 3 TO SUBPART CCCCCC OF PART 63.—APPLICABILITY OF GENERAL PROVISIONS
Subject
Brief description
Applies to subpart
CCCCCC
§ 63.1 ...................................
Applicability ........................
Title V Permit .....................
Initial applicability determination; applicability after
standard established; permit requirements; extensions, notifications.
Requirements for obtaining a title V permit from the
applicable permitting authority.
Yes, specific requirements
given in § 63.11111.
§ 63.1(c)(2) ...........................
§ 63.2 ...................................
yshivers on PROD1PC62 with RULES2
Citation
Definitions ..........................
Definitions for part 63 standards ...................................
§ 63.3 ...................................
§ 63.4 ...................................
Units and Abbreviations ....
Prohibited Activities and
Circumvention.
Construction/Reconstruction.
Units and abbreviations for part 63 standards ..............
Prohibited activities; Circumvention, severability ..........
Yes, § 63.11111(f) of subpart CCCCCC exempts
identified area sources
from the obligation to obtain title V operating permits.
Yes, additional definitions
in § 63.11132.
Yes.
Yes.
Applicability; applications; approvals .............................
Yes.
§ 63.5 ...................................
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
PO 00000
Frm 00035
Fmt 4701
Sfmt 4700
E:\FR\FM\10JAR2.SGM
10JAR2
1950
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
TABLE 3 TO SUBPART CCCCCC OF PART 63.—APPLICABILITY OF GENERAL PROVISIONS—Continued
Citation
Subject
§ 63.6(a) ...............................
Compliance with Standards/Operation & Maintenance—Applicability.
Compliance Dates for New
and Reconstructed
Sources.
Notification .........................
§ 63.6(b)(1)–(4) ....................
§ 63.6(b)(5) ..........................
§ 63.6(b)(6) ..........................
§ 63.6(b)(7) ..........................
§ 63.6(c)(1)–(2) ....................
§ 63.6(c)(3)–(4) ....................
§ 63.6(c)(5) ...........................
§ 63.6(d) ...............................
§ 63.6(e)(1) ..........................
§ 63.6(e)(2) ..........................
§ 63.6(e)(3) ..........................
§ 63.6(f)(1) ...........................
§ 63.6(f)(2)–(3) .....................
§ 63.6(g)(1)–(3) ....................
§ 63.6(h)(1) ..........................
§ 63.6(h)(2)(i) .......................
§ 63.6(h)(2)(ii) ......................
§ 63.6(h)(2)(iii) ......................
§ 63.6(h)(3) ..........................
§ 63.6(h)(4) ..........................
§ 63.6(h)(5)(i), (iii)–(v) ..........
§ 63.6(h)(5)(ii) ......................
§ 63.6(h)(6) ..........................
yshivers on PROD1PC62 with RULES2
§ 63.6(h)(7)(i) .......................
§ 63.6(h)(7)(ii) ......................
§ 63.6(h)(7)(iii) ......................
VerDate Aug<31>2005
14:31 Jan 09, 2008
Applies to subpart
CCCCCC
Brief description
[Reserved].
Compliance Dates for New
and Reconstructed Area
Sources That Become
Major.
Compliance Dates for Existing Sources.
General Provisions apply unless compliance exten- Yes.
sion; General Provisions apply to area sources that
become major.
Standards apply at effective date; 3 years after effec- Yes.
tive date; upon startup; 10 years after construction
or reconstruction commences for CAA section 112(f).
Must notify if commenced construction or reconstruc- Yes.
tion after proposal.
Area sources that become major must comply with
major source standards immediately upon becoming
major, regardless of whether required to comply
when they were an area source.
Comply according to date in this subpart, which must
be no later than 3 years after effective date; for
CAA section 112(f) standards, comply within 90
days of effective date unless compliance extension.
No.
Area sources That become major must comply with
major source standards by date indicated in this
subpart or by equivalent time period (e.g., 3 years).
No.
Operate to minimize emissions at all times; correct
malfunctions as soon as practicable; and operation
and maintenance requirements independently enforceable; information Administrator will use to determine if operation and maintenance requirements
were met.
Yes.
Requirement for SSM plan; content of SSM plan; actions during SSM.
You must comply with emission standards at all times
except during SSM.
Compliance based on performance test, operation and
maintenance plans, records, inspection.
Procedures for getting an alternative standard .............
You must comply with opacity/VE standards at all
times except during SSM.
No.
If standard does not State test method, use EPA
Method 9 for opacity in appendix A of part 60 of this
chapter and EPA Method 22 for VE in appendix A
of part 60 of this chapter.
No.
Criteria for when previous opacity/VE testing can be
used to show compliance with this subpart.
No.
Must notify Administrator of anticipated date of observation.
Dates and schedule for conducting opacity/VE observations.
Must have at least 3 hours of observation with 30 6minute averages.
Must keep records available and allow Administrator
to inspect.
No.
Must submit COMS data with other performance test
data.
No.
Can submit COMS data instead of EPA Method 9 results even if rule requires EPA Method 9 in appendix A of part 60 of this chapter, but must notify Administrator before performance test.
Averaging Time for COMS To determine compliance, must reduce COMS data to
During Performance Test.
6-minute averages.
No.
[Reserved].
Compliance Dates for Existing Area Sources That
Become Major.
[Reserved].
Operation & Maintenance
[Reserved].
Startup, Shutdown, and
Malfunction (SSM) Plan.
Compliance Except During
SSM.
Methods for Determining
Compliance.
Alternative Standard ..........
Compliance with Opacity/
Visible Emission (VE)
Standards.
Determining Compliance
with Opacity/VE Standards.
[Reserved].
Using Previous Tests To
Demonstrate Compliance With Opacity/VE
Standards.
[Reserved].
Notification of Opacity/VE
Observation Date.
Conducting Opacity/VE
Observations.
Opacity Test Duration and
Averaging Times.
Records of Conditions During Opacity/VE Observations.
Report Continuous Opacity
Monitoring System
(COMS) Monitoring Data
From Performance Test.
Using COMS Instead of
EPA Method 9.
Jkt 214001
PO 00000
Frm 00036
Fmt 4701
Sfmt 4700
E:\FR\FM\10JAR2.SGM
10JAR2
No, § 63.11113 specifies
the compliance dates.
No.
Yes.
Yes.
No.
No.
No.
No.
No.
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
1951
TABLE 3 TO SUBPART CCCCCC OF PART 63.—APPLICABILITY OF GENERAL PROVISIONS—Continued
Applies to subpart
CCCCCC
Subject
Brief description
§ 63.6(h)(7)(iv) .....................
COMS Requirements ........
Determining Compliance
with Opacity/VE Standards.
§ 63.6(h)(8) ..........................
Determining Compliance
with Opacity/VE Standards.
§ 63.6(h)(9) ..........................
Adjusted Opacity Standard
§ 63.6(i)(1)–(14) ...................
Compliance Extension .......
§ 63.6(j) ................................
§ 63.7(a)(2) ..........................
Presidential Compliance
Exemption.
Performance Test Dates ...
§ 63.7(a)(3) ..........................
CAA Section 114 Authority
§ 63.7(b)(1) ..........................
§ 63.7(b)(2) ..........................
Notification of Performance
Test.
Notification of Re-scheduling.
Owner/operator must demonstrate that COMS performance evaluations are conducted according to
§ 63.8(e); COMS are properly maintained and operated according to § 63.8(c) and data quality as
§ 63.8(d).
COMS is probable but not conclusive evidence of
compliance with opacity standard, even if EPA
Method 9 observation shows otherwise. Requirements for COMS to be probable evidence-proper
maintenance, meeting Performance Specification 1
in appendix B of part 60 of this chapter, and data
have not been altered.
Administrator will use all COMS, EPA Method 9 (in
appendix A of part 60 of this chapter), and EPA
Method 22 (in appendix A of part 60 of this chapter)
results, as well as information about operation and
maintenance to determine compliance.
Procedures for Administrator to adjust an opacity
standard.
Procedures and criteria for Administrator to grant compliance extension.
President may exempt any source from requirement to
comply with this subpart.
Dates for conducting initial performance testing; must
conduct 180 days after compliance date.
Administrator may require a performance test under
CAA section 114 at any time.
Must notify Administrator 60 days before the test ........
No.
§ 63.6(h)(7)(v) ......................
Quality Assurance (QA)/
Test Plan.
§ 63.7(d) ...............................
§ 63.7(e)(1) ..........................
Testing Facilities ................
Conditions for Conducting
Performance Tests.
§ 63.7(e)(2) ..........................
§ 63.7(e)(3) ..........................
Conditions for Conducting
Performance Tests.
Test Run Duration .............
§ 63.7(f) ................................
Alternative Test Method ....
§ 63.7(g) ...............................
Performance Test Data
Analysis.
§ 63.7(h) ...............................
Waiver of Tests .................
§ 63.8(a)(1) ..........................
§ 63.8(a)(2) ..........................
Applicability of Monitoring
Requirements.
Performance Specifications
If have to reschedule performance test, must notify
Administrator of rescheduled date as soon as practicable and without delay.
Requirement to submit site-specific test plan 60 days
before the test or on date Administrator agrees with;
test plan approval procedures; performance audit
requirements; internal and external QA procedures
for testing.
Requirements for testing facilities .................................
Performance tests must be conducted under representative conditions; cannot conduct performance
tests during SSM.
Must conduct according to this subpart and EPA test
methods unless Administrator approves alternative.
Must have three test runs of at least 1 hour each;
compliance is based on arithmetic mean of three
runs; conditions when data from an additional test
run can be used.
Procedures by which Administrator can grant approval
to use an intermediate or major change, or alternative to a test method.
Must include raw data in performance test report;
must submit performance test data 60 days after
end of test with the Notification of Compliance Status; keep data for 5 years.
Procedures for Administrator to waive performance
test.
Subject to all monitoring requirements in standard ......
Yes.
§ 63.7(c) ...............................
yshivers on PROD1PC62 with RULES2
Citation
§ 63.8(a)(3) ..........................
§ 63.8(a)(4) ..........................
§ 63.8(b)(1) ..........................
[Reserved].
Monitoring of Flares ..........
Monitoring ..........................
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
PO 00000
No.
No.
No.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Yes.
Performance Specifications in appendix B of 40 CFR
part 60 apply.
Yes.
Monitoring requirements for flares in § 63.11 apply ......
Must conduct monitoring according to standard unless
Administrator approves alternative.
Yes.
Yes.
Frm 00037
Fmt 4701
Sfmt 4700
E:\FR\FM\10JAR2.SGM
10JAR2
1952
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
TABLE 3 TO SUBPART CCCCCC OF PART 63.—APPLICABILITY OF GENERAL PROVISIONS—Continued
Applies to subpart
CCCCCC
Citation
Subject
Brief description
§ 63.8(b)(2)–(3) ....................
Multiple Effluents and Multiple Monitoring Systems.
No.
§ 63.8(c)(1) ...........................
Monitoring System Operation and Maintenance.
Routine and Predictable
SSM.
Specific requirements for installing monitoring systems; must install on each affected source or after
combined with another affected source before it is
released to the atmosphere provided the monitoring
is sufficient to demonstrate compliance with the
standard; if more than one monitoring system on an
emission point, must report all monitoring system results, unless one monitoring system is a backup.
Maintain monitoring system in a manner consistent
with good air pollution control practices.
Follow the SSM plan for routine repairs; keep parts for
routine repairs readily available; reporting requirements for SSM when action is described in SSM
plan.
Must install to get representative emission or parameter measurements; must verify operational status
before or at performance test.
Requirements for CMS quality control, including calibration, etc.; must keep quality control plan on
record for 5 years; keep old versions for 5 years
after revisions.
Notification, performance evaluation test plan, reports
Procedures for Administrator to approve alternative
monitoring.
Procedures for Administrator to approve alternative
relative accuracy tests for continuous emissions
monitoring system (CEMS).
COMS 6-minute averages calculated over at least 36
evenly spaced data points; CEMS 1 hour averages
computed over at least 4 equally spaced data
points; data that cannot be used in average.
Applicability and State delegation .................................
Submit notification within 120 days after effective date;
notification of intent to construct/reconstruct, notification of commencement of construction/reconstruction, notification of startup; contents of each.
Can request if cannot comply by date or if installed
best available control technology or lowest achievable emission rate.
For sources that commence construction between proposal and promulgation and want to comply 3 years
after effective date.
Notify Administrator 60 days prior .................................
No.
Yes.
Yes.
Notify Administrator 30 days prior .................................
No.
Notification of performance evaluation; notification
about use of COMS data; notification that exceeded
criterion for relative accuracy alternative.
Contents due 60 days after end of performance test or
other compliance demonstration, except for opacity/
VE, which are due 30 days after; when to submit to
Federal vs. State authority.
Procedures for Administrator to approve change when
notifications must be submitted.
Must submit within 15 days after the change ...............
Yes, however, there are no
opacity standards.
Applies to all, unless compliance extension; when to
submit to Federal vs. State authority; procedures for
owners of more than one source.
General requirements; keep all records readily available; keep for 5 years.
Occurrence of each for operations (process equipment); occurrence of each malfunction of air pollution control equipment; maintenance on air pollution
control equipment; actions during SSM.
Malfunctions, inoperative, out-of-control periods ..........
Records when under waiver .........................................
Records when using alternative to relative accuracy
test.
Yes.
§ 63.8(c)(1)(i)–(iii) .................
§ 63.8(c)(2)–(8) ....................
§ 63.8(d) ...............................
§ 63.8(e) ...............................
§ 63.8(f)(1)–(5) .....................
§ 63.8(f)(6) ...........................
Continuous Monitoring
System (CMS) Requirements.
CMS Quality Control .........
CMS Performance Evaluation.
Alternative Monitoring
Method.
Alternative to Relative Accuracy Test.
§ 63.8(g) ...............................
Data Reduction ..................
§ 63.9(a) ...............................
§ 63.9(b)(1)–(2), (4)–(5) .......
Notification Requirements
Initial Notifications .............
§ 63.9(c) ...............................
Request for Compliance
Extension.
§ 63.9(d) ...............................
Notification of Special
Compliance Requirements for New Sources.
Notification of Performance
Test.
Notification of VE/Opacity
Test.
Additional Notifications
when Using CMS.
§ 63.9(e) ...............................
§ 63.9(f) ................................
§ 63.9(g) ...............................
§ 63.9(h)(1)–(6) ....................
Notification of Compliance
Status.
§ 63.9(i) ................................
§ 63.10(a) .............................
Adjustment of Submittal
Deadlines.
Change in Previous Information.
Recordkeeping/Reporting ..
§ 63.10(b)(1) ........................
Recordkeeping/Reporting ..
§ 63.10(b)(2)(i)–(iv) ..............
Records Related to SSM ..
§ 63.10(b)(2)(vi)–(xi) ............
§ 63.10(b)(2)(xii) ...................
§ 63.10(b)(2)(xiii) ..................
CMS Records ....................
Records .............................
Records .............................
yshivers on PROD1PC62 with RULES2
§ 63.9(j) ................................
VerDate Aug<31>2005
14:31 Jan 09, 2008
Jkt 214001
PO 00000
Frm 00038
Fmt 4701
Sfmt 4700
E:\FR\FM\10JAR2.SGM
10JAR2
No.
No.
No.
No.
No.
No.
No.
Yes.
Yes.
Yes.
Yes, however, there are no
opacity standards.
Yes.
Yes.
Yes.
No.
No.
Yes.
Yes.
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 / Rules and Regulations
1953
TABLE 3 TO SUBPART CCCCCC OF PART 63.—APPLICABILITY OF GENERAL PROVISIONS—Continued
Applies to subpart
CCCCCC
Citation
Subject
Brief description
§ 63.10(b)(2)(xiv) ..................
Records .............................
§ 63.10(b)(3) ........................
§ 63.10(c) .............................
§ 63.10(d)(1) ........................
Yes.
No.
Yes.
When to submit to Federal or State authority ...............
Yes.
What to report and when ..............................................
No.
§ 63.10(d)(4) ........................
Records .............................
Records .............................
General Reporting Requirements.
Report of Performance
Test Results.
Reporting Opacity or VE
Observations.
Progress Reports ..............
All documentation supporting Initial Notification and
Notification of Compliance Status.
Applicability determinations ...........................................
Additional records for CMS ...........................................
Requirement to report ...................................................
Yes.
§ 63.10(d)(5) ........................
§ 63.10(e)(1)–(2) ..................
SSM Reports .....................
Additional CMS Reports ....
§ 63.10(e)(3)(i)–(iii) ..............
Reports ..............................
Must submit progress reports on schedule if under
compliance extension.
Contents and submission ..............................................
Must report results for each CEMS on a unit; written
copy of CMS performance evaluation; two-three
copies of COMS performance evaluation.
Schedule for reporting excess emissions .....................
§ 63.10(e)(3)(iv)–(v) .............
Excess Emissions Reports
§ 63.10(e)(3)(vi)–(viii) ...........
Excess Emissions Report
and Summary Report.
§ 63.10(e)(4) ........................
§ 63.10(f) ..............................
Reporting COMS Data ......
Waiver for Recordkeeping/
Reporting.
Flares .................................
Delegation .........................
Addresses ..........................
§ 63.10(d)(2) ........................
§ 63.10(d)(3) ........................
§ 63.11(b) .............................
§ 63.12 .................................
§ 63.13 .................................
§ 63.14 .................................
§ 63.15 .................................
Incorporations by Reference.
Availability of Information ..
Requirement to revert to quarterly submission if there
is an excess emissions and parameter monitor
exceedances (now defined as deviations); provision
to request semiannual reporting after compliance for
1 year; submit report by 30th day following end of
quarter or calendar half; if there has not been an
exceedance or excess emissions (now defined as
deviations), report contents in a statement that there
have been no deviations; must submit report containing all of the information in §§ 63.8(c)(7)–(8) and
63.10(c)(5)–(13).
Requirements for reporting excess emissions for CMS;
requires all of the information in §§ 63.10(c)(5)–(13)
and 63.8(c)(7)–(8).
Must submit COMS data with performance test data ...
Procedures for Administrator to waive ..........................
yshivers on PROD1PC62 with RULES2
Jkt 214001
PO 00000
Yes, note that
§ 63.11130(K) specifies
excess emission events
for this subpart.
No, § 63.11130(K) specifies excess emission
events for this subpart.
No.
No.
Yes.
No.
Yes.
Yes.
Public and confidential information ...............................
Yes.
BILLING CODE 6560–50–P
14:31 Jan 09, 2008
Yes.
No.
Requirements for flares .................................................
State authority to enforce standards .............................
Addresses where reports, notifications, and requests
are sent.
Test methods incorporated by reference ......................
[FR Doc. E7–25400 Filed 1–9–08; 8:45 am]
VerDate Aug<31>2005
Yes.
Frm 00039
Fmt 4701
Sfmt 4700
E:\FR\FM\10JAR2.SGM
10JAR2
Yes.
Agencies
[Federal Register Volume 73, Number 7 (Thursday, January 10, 2008)]
[Rules and Regulations]
[Pages 1916-1953]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: E7-25400]
[[Page 1915]]
-----------------------------------------------------------------------
Part II
Environmental Protection Agency
-----------------------------------------------------------------------
40 CFR Part 63
National Emission Standards for Hazardous Air Pollutants for Source
Categories: Gasoline Distribution Bulk Terminals, Bulk Plants, and
Pipeline Facilities; and Gasoline Dispensing Facilities; Final Rule
Federal Register / Vol. 73, No. 7 / Thursday, January 10, 2008 /
Rules and Regulations
[[Page 1916]]
-----------------------------------------------------------------------
ENVIRONMENTAL PROTECTION AGENCY
40 CFR Part 63
[EPA-HQ-OAR-2006-0406, FRL-8512-3]
RIN 2060-AM74
National Emission Standards for Hazardous Air Pollutants for
Source Categories: Gasoline Distribution Bulk Terminals, Bulk Plants,
and Pipeline Facilities; and Gasoline Dispensing Facilities
AGENCY: Environmental Protection Agency (EPA).
ACTION: Final rule.
-----------------------------------------------------------------------
SUMMARY: This action promulgates national emission standards for
hazardous air pollutants for the facilities in the gasoline
distribution (Stage I) area source category. We are promulgating these
emission standards for hazardous air pollutants pursuant to Clean Air
Act section 112(c)(3) and 112(d)(5). We are adding two regulations that
address the facilities contained in this area source category. The
first includes requirements for bulk distribution facilities, i.e.,
gasoline distribution bulk terminals, bulk plants, and pipeline
facilities. The second includes requirements for loading of storage
tanks at gasoline dispensing facilities. We are also incorporating by
reference four test methods. This action also finalizes our decision
not to regulate the above noted facilities under Clean Air Act section
112(c)(6).
DATES: These final rules are effective on January 10, 2008. The
incorporation by reference of certain publications listed in the rule
is approved by the Director of the Federal Register as of January 10,
2008.
ADDRESSES: EPA has established a docket for this action under Docket ID
No. EPA-HQ-OAR-2006-0406. All documents in the docket are listed on the
www.regulations.gov Web site. Although listed in the index, some
information is not publicly available, e.g., confidential business
information or other information whose disclosure is restricted by
statute. Certain other material, such as copyrighted material, is not
placed on the Internet and will be publicly available only in hard copy
form. Publicly available docket materials are available either
electronically through www.regulations.gov or in hard copy at the Air
and Radiation Docket in the EPA Headquarters Library, EPA West
Building, Room 3334, 1301 Constitution Ave., NW., Washington, DC. 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. The Air and Radiation Docket and
Information Center's Web site is: https://www.epa.gov/oar/docket.html.
The electronic mail (e-mail) address for the Air and Radiation Docket
is: a-and-r-Docket@epa.gov, the telephone number is (202) 566-1742, and
the Fax number is (202) 566-9744.
FOR FURTHER INFORMATION CONTACT: General and Technical Information: Mr.
Stephen Shedd, Office of Air Quality Planning and Standards, Sector
Policies and Programs Division, Coatings and Chemicals Group (E143-01),
EPA, Research Triangle Park, NC 27711, telephone: (919) 541-5397,
facsimile number: (919) 685-3195, e-mail address: shedd.steve@epa.gov.
Economic Analysis Information: Mr. Tom Walton, Office of Air
Quality Planning and Standards, Health and Environmental Impacts
Division, Air Benefit and Cost Group (C339-01), EPA, Research Triangle
Park, NC 27711, telephone: (919) 541-5311, facsimile number: (919) 541-
0242, e-mail address: walton.tom@epa.gov.
Compliance Information: Ms. Maria Malave, Office of Compliance, Air
Compliance Branch (2223A), EPA, Ariel Rios Building, 1200 Pennsylvania
Avenue, NW., Washington, DC 20460, telephone: (202) 564-7027, facsimile
number: (202) 564-0050, e-mail address: malave.maria@epa.gov.
SUPPLEMENTARY INFORMATION:
Outline. The information presented in this preamble is organized as
follows:
I. General Information
A. Does this action apply to me?
B. Where can I get a copy of this document?
C. Judicial Review
II. Background Information
III. Summary of Final Rules and Changes Since Proposal
A. Applicability and Compliance Dates
B. Summary of Emission Limits and Management Practices
C. What are the testing and initial compliance requirements?
D. What are the notification, recordkeeping, and reporting
requirements?
E. Summary of Major Changes Since Proposal
IV. Additional Actions
A. Title V Permitting Requirements
B. Not Regulating This Source Category Under CAA Section
112(c)(6)
V. Summary of Comments and Responses
A. Applicability
B. Selection of Regulatory Alternative
C. Bulk Terminals
D. Testing and Monitoring
E. Control Costs and Cost Analyses Performed
F. Notifications, Reporting, and Recordkeeping
VI. Summary of Environmental, Energy, Cost, and Economic Impacts
A. What are the air impacts?
B. What are the cost impacts?
C. What are the economic impacts?
D. What are the non-air environmental and energy impacts?
VII. 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 Risks and Safety Risks
H. Executive Order 13211: Actions Concerning Regulations That
Significantly Affect Energy Supply, Distribution, or Use
I. National Technology Transfer and Advancement Act
J. Executive Order 12898: Federal Actions To Address
Environmental Justice in Minority Populations and Low-Income
Populations
K. Congressional Review Act
I. General Information
A. Does this action apply to me?
The regulated categories and entities affected by these final rules
include:
------------------------------------------------------------------------
Examples of regulated
Category NAICS \a\ entities
------------------------------------------------------------------------
Industry....................... 324110 Operations at area
493190 sources that transfer
486910 and store gasoline,
424710 including bulk
447110 terminals, bulk
447190 plants, pipeline
facilities, and
gasoline dispensing
facilities.
Federal/State/local/tribal
governments .
------------------------------------------------------------------------
\a\ North American Industry Classification System.
[[Page 1917]]
This table is not intended to be exhaustive, but rather provides a
guide for readers regarding entities likely to be affected by the
national emission standards. To determine whether your facility will be
affected by the national emission standards, you should examine the
applicability criteria in these final rules. If you have any questions
regarding the applicability of the national emission standards to a
particular entity, consult either the air permit authority for the
entity or your EPA regional representative as listed in 40 CFR 63.13.
B. Where can I get a copy of this document?
In addition to being available in the docket, an electronic copy of
these final rules is also available on the World Wide Web through the
Technology Transfer Network (TTN). Following signature, a copy of these
final rules will be posted on the TTN's policy and guidance page for
newly proposed or promulgated rules at the following address: https://
www.epa.gov/ttn/oarpg/. The TTN provides information and technology
exchange in various areas of air pollution control.
C. Judicial Review
Under section 307(b)(1) of the Clean Air Act (CAA), judicial review
of these final rules is available only by filing a petition for review
in the United States Court of Appeals for the District of Columbia
Circuit by March 10, 2008. Under section 307(b)(2) of the CAA, the
requirements established by these final rules may not be challenged
separately in any civil or criminal proceedings brought by EPA to
enforce these requirements.
Section 307(d)(7)(B) of the CAA further provides that ``[o]nly an
objection to a rule or procedure which was raised with reasonable
specificity during the period for public comment (including any public
hearing) may be raised during judicial review.'' This section also
provides a mechanism for us to convene a proceeding for
reconsideration, ``[i]f the person raising an objection can demonstrate
to the EPA that it was impracticable to raise such objection within
[the period for public comment] or if the grounds for such objection
arose after the period for public comment (but within the time
specified for judicial review) and if such objection is of central
relevance to the outcome of the rule.'' Any person seeking to make such
a demonstration to us should submit a Petition for Reconsideration to
the Office of the Administrator, U.S. EPA, Room 3000, Ariel Rios
Building, 1200 Pennsylvania Ave., NW., Washington, DC 20460, with a
copy to both the persons(s) listed in the preceding FOR FURTHER
INFORMATION CONTACT section, and the Associate General Counsel for the
Air and Radiation Law Office, Office of General Counsel (Mail Code
2344A), U.S. EPA, 1200 Pennsylvania Ave., NW., Washington, DC 20460.
II. Background Information
On December 14, 1994 (59 FR 64303), we promulgated national
emission standards for hazardous air pollutants (NESHAP) for major
source facilities within the gasoline distribution source category (see
40 CFR part 63, subpart R (Major Source NESHAP)). The Major Source
NESHAP imposed control requirements on sources within the source
category that met the definition of major sources, e.g., a source that
emits 10 tons per year or more of any individual hazardous air
pollutant (HAP) or 25 tons per year or more of any combination of HAP.
Gasoline vapors normally contain nine HAP: benzene, ethylbenzene,
hexane, toluene, xylenes, isooctane, naphthalene, cumene, and methyl
tert-butyl ether. Some gasoline distribution terminals and pipeline
facilities were found to be major sources by themselves or to be
located at major sources. Gasoline storage tanks at bulk terminals and
pipeline breakout stations, loading racks at bulk terminals, vapor
leaks from gasoline cargo tanks, and equipment components in gasoline
service were emission sources that were regulated under the Major
Source NESHAP. Area sources of HAP emissions within the source category
(many bulk terminals and pipeline breakout stations and all pipeline
pumping stations, bulk plants, and gasoline dispensing facilities (GDF)
(service stations, convenience stores, and other retail outlets)) are
not subject to the Major Source NESHAP.
Section 112(k)(3)(B) of the CAA requires EPA to identify at least
30 HAP which, as the result of emissions from area sources,\1\ pose the
greatest threat to public health in urban areas. Consistent with this
provision, in 1999, in the Integrated Urban Air Toxics Strategy
(Strategy), EPA identified the 30 HAP that pose the greatest potential
health threat in urban areas, and these HAP are referred to as the
``urban HAP.'' See 64 FR 38706, 38715-716, July 19, 1999. Section
112(c)(3) requires EPA to list sufficient categories or subcategories
of area sources to ensure that area sources representing 90 percent of
the emissions of the 30 urban HAP are subject to regulation. EPA listed
the source categories that account for 90 percent of the urban HAP
emissions in the Strategy.\2\
---------------------------------------------------------------------------
\1\ An area source is a stationary source of HAP emissions that
is not a major source.
\2\ Since its publication in the Integrated Urban Air Toxics
Strategy in 1999, the area source category list has undergone
several amendments.
---------------------------------------------------------------------------
CAA Section 112(d) standards include new and existing source
maximum achievable control technology (MACT) standards, health
threshold standards, and generally available control technology or
management practices (GACT) standards for area sources. The standards
that are the subject of these final rules are based on GACT pursuant to
CAA section 112(d)(5).
Gasoline vapors contain two HAP (benzene and ethylene dichloride
(EDC)) included among the 30 area source HAP listed under the Strategy.
The gasoline distribution (Stage I) area source category was listed in
the Strategy because the facilities in this category contributed
approximately 36 percent of the national emissions of benzene and 2
percent of the EDC emissions from stationary area sources. We are
adding two subparts to 40 CFR part 63 to address the benzene emissions
from the facilities in this area source category. As explained in the
proposed rule, EDC emissions are no longer emitted from facilities in
this area source category as a result of the lead phase-down provisions
of section 218 of the CAA. We received no comments on this matter;
therefore, we are taking no further action regarding EDC emissions in
this rulemaking.
III. Summary of Final Rules and Changes Since Proposal
This section summarizes the final rules and identifies and
discusses changes since proposal. For changes that were made as a
result of public comments, we have provided explanations of the changes
and the rationale in the responses to comments in section V of this
preamble.
A. Applicability and Compliance Dates
These final rules apply to any existing or new gasoline
distribution facility that is an area source. 40 CFR part 63, subpart
BBBBBB applies to bulk gasoline terminals, pipeline facilities, and
bulk gasoline plants. 40 CFR part 63, subpart CCCCCC applies to GDF.
The owner or operator of an existing area source must comply with all
the requirements of these final rules by January 10, 2011. The owner or
operator of a new area source must comply with these final rules by
January 10, 2008 or upon initial startup, whichever is later.
[[Page 1918]]
B. Summary of Emission Limits and Management Practices
40 CFR part 63, subpart BBBBBB requires that area source bulk
gasoline terminals and pipeline breakout stations \3\ that meet the
applicability criteria in 40 CFR 63.11081 control emissions from large
storage tanks (those at or above 20,000 gallons capacity) by using
either specified floating roofs and seals or a closed vent system and
control device to reduce emissions by 95 percent. Small storage tanks
(those below 20,000 gallons capacity) must be covered.
---------------------------------------------------------------------------
\3\ See 40 CFR 63.11100 for the definitions of the specific
facilities regulated under subpart BBBBBB.
---------------------------------------------------------------------------
40 CFR part 63, subpart BBBBBB also requires that cargo tank
loading rack emissions located at bulk gasoline terminals with gasoline
throughputs above 250,000 gallons per day be reduced to a level of 80
milligrams (mg), or less, per liter of gasoline loaded into cargo
tanks. Those bulk terminals with gasoline throughputs below 250,000
gallons per day must use submerged filling for the loading of cargo
tanks.
Additionally, bulk terminal owners or operators with gasoline
throughputs above 250,000 gallons per day must not allow the loading of
cargo tanks that do not have the appropriate vapor tightness testing
documentation. Before loading at an affected bulk terminal, the owner
or operator of a cargo tank must present documentation of passing the
vapor tightness test to demonstrate, using EPA Reference Method 27, or
equivalent, that they meet a maximum pressure or vacuum decay rate of 3
inches of water, or less, during a 5-minute test period.
At bulk plants, 40 CFR part 63, subpart BBBBBB requires the use of
submerged filling of gasoline storage tanks and cargo tanks.
40 CFR part 63, subpart BBBBBB also requires the implementation of
a monthly equipment leak inspection at bulk terminals, bulk plants,
pipeline breakout stations, and pipeline pumping stations. The
standards allow a sight, sound, and smell inspection of all equipment
components in gasoline liquid or vapor service. In the final rule, all
leaking equipment components must be repaired within a specified time
period.
40 CFR part 63, subpart CCCCCC requires controls at GDF nationwide
depending on the GDF's monthly gasoline throughput. All GDF must
perform specified good management practices to check for and minimize
evaporation of gasoline. All those GDF above 10,000 gallons per month
throughput must also employ submerged filling of gasoline storage
tanks. The submerged filling requirement is met by either bottom
filling the storage tank or by using a fill pipe to load the storage
tank that extends to no more than 12 inches from the bottom of the
storage tank for fill pipes installed on or before November 9, 2006,
and no more than 6 inches from the bottom of the storage tank for fill
pipes installed after November 9, 2006. Additionally, those GDF with a
monthly throughput of 100,000 gallons, or more, must also use vapor
balancing when filling their gasoline storage tanks.
Additionally, under the final rule, GDF that have tanks with a 250
gallon capacity or less, regardless of monthly throughput, are only
required to perform the good management practices to check for and
minimize evaporation of gasoline described in section 63.11116(a);
these tanks are not required to comply with either the submerged fill
or vapor balancing requirements of the final rule.
C. What are the testing and initial compliance requirements?
40 CFR part 63, subpart BBBBBB requires that control devices being
used to reduce emissions from loading racks at bulk terminals be tested
to demonstrate that they comply with the emission limit. Closed vent
systems and control devices used to reduce emissions from storage tanks
also have to be tested to demonstrate that they comply with the
emission limit. Other options for demonstrating compliance with the
rule include using recent performance tests or providing documentation
that the devices are complying with enforceable State, local, or tribal
rules or operating permits that contain requirements at least as
stringent as this final rule.
Affected facilities that use control devices (vapor processors) to
comply with the emission limits for storage tanks or loading racks at
bulk terminals are required to monitor operating parameters to
demonstrate continuous compliance with the emission limits. The
monitored operating parameter values must be determined during a
performance test or by engineering assessment. An operating parameter
monitoring approach approved by the Administrator and included in an
enforceable operating permit is allowed as an alternative.
Annual inspections of storage tank roofs and seals are required for
bulk terminals and pipeline breakout stations. Such inspections must be
conducted using either the procedures required in 40 CFR part 60,
subpart Kb, Standards of Performance for Volatile Organic Liquid
Storage Vessels (Storage Vessels New Source Performance Standards
(NSPS)) or the procedures required in 40 CFR part 63, subpart WW
(National Emission Standards for Storage Vessels (Tanks)--Control Level
2).
In addition, each owner or operator of a bulk gasoline terminal is
required to monitor the loading of gasoline into gasoline cargo tanks
to limit the loading to vapor-tight gasoline cargo tanks. The owner or
operator of each gasoline cargo tank loading at an affected bulk
terminal is required to perform vapor tightness testing on each cargo
tank to demonstrate compliance with the maximum allowable pressure and
vacuum change of 3 inches of water, or less, in 5 minutes. Vapor
tightness testing must be performed using EPA Reference Method 27.
Railcar cargo tanks may also use the ``Railcar Bubble Leak Test
Procedures'' specified in the rule.
40 CFR part 63, Subpart CCCCCC requires that the owner or operator
of GDF meeting the applicability criteria for vapor balancing
demonstrate initial compliance with this emission limit by conducting
an initial performance test on the vapor balance system. The rule also
contains other options for demonstrating compliance with this emission
limit, such as using recent performance tests or providing
documentation that the vapor balance systems are complying with
enforceable State, local, or tribal rules or operating permits that
contain requirements at least as stringent as this final rule.
Each owner or operator must also determine, at the time of
installation and every 3 years thereafter, the leak rate and cracking
pressure of pressure-vacuum vent valves installed on gasoline storage
tanks and must conduct a static pressure test on gasoline storage
tanks.
D. What are the notification, recordkeeping, and reporting
requirements?
Affected sources that are subject to the control requirements under
these final rules are required to submit four types of notifications or
reports as set forth in the General Provisions: (1) Initial
Notification; (2) Notification of Compliance Status; (3) periodic
reports; and (4) other reports. The Initial Notification alerts the
regulatory authority of applicability for existing sources or of
construction for new sources. This notification also includes a
statement as to whether the facility can achieve compliance by the
required compliance date. The Notification of Compliance Status
demonstrates that compliance has been achieved. This
[[Page 1919]]
notification contains the results of initial performance tests and a
list of equipment subject to the standard. Periodic reports are
required on a semi-annual basis. The semi-annual compliance report
informs the regulatory authority of the results of required inspections
or additional testing results. An excess emissions report, if
applicable, must be submitted with the semi-annual compliance report
and is required if excess emission events occur. Excess emission events
include events such as the loading of a cargo tank that does not have
documentation of vapor tightness testing, deviations from acceptable
operating parameter values, or equipment leaks that are not repaired
within the required time.
Other reports are also required under the General Provisions,
generally on a one-time basis, for events such as a notification before
a performance test or a storage vessel inspection. Reporting these
events allows the regulatory authority the opportunity to have an
observer present.
Reporting requirements for owners or operators of bulk plants and
GDF are limited in most cases to the Initial Notification and the
Notification of Compliance Status. Those bulk plants that are located
in States that require the use of submerged fill would not be required
to submit these notifications. The same is true for GDF located in
States or counties that already require submerged fill or submerged
fill plus vapor balancing.
Records required under these final rules must be kept for 5 years.
These include records of cargo tank vapor tightness test
certifications, records of storage tank and equipment component
inspections, and records of monthly throughput.
E. Summary of Major Changes Since Proposal
As a result of the public comments received in response to the
November 9, 2006 proposal, we have made several changes in the final
rules for this source category. This section presents a summary of the
major changes since proposal. Additional discussion of the details of
the changes and the rationale for making these changes is presented in
section V of this preamble.
As proposed, 40 CFR part 63, subpart BBBBBB applied to both bulk
facilities nationwide and GDF in Urban 1 and Urban 2 areas. We also
requested comment on whether to require vapor balancing at GDF in Urban
1 areas and provided rule text in the docket. In order to simplify the
final rules, we have included the requirements for bulk facilities in
subpart BBBBBB and have included all requirements for GDF in a separate
subpart (40 CFR part 63, subpart CCCCCC).
We have made some changes to the requirements for bulk facilities.
Internal floating roof storage tanks at bulk terminals and pipeline
breakout stations will not have to be equipped with secondary rim seals
(as proposed) if they have vapor mounted primary seals. Also, we are
clarifying that storage tanks below 20,000 gallons in capacity require
a cover, and those at or above 20,000 gallons in capacity require the
controls as proposed and mentioned above.
We have also made some changes to the requirements for loading
racks at bulk terminals. We proposed a requirement that all bulk
terminals meet an 80 mg per liter (mg/l) emission standard for loading
racks. Based on comments received, however, the type of control
required in the final rule depends on the daily gasoline throughput of
the bulk terminal. Loading racks at bulk terminals with daily gasoline
throughputs of less than 250,000 gallons are required to use submerged
filling; those at or above a daily gasoline throughput of 250,000
gallons are required to meet the 80 mg/l standard.
Additionally, we requested comment and supporting information on
alternative parameter monitoring approaches for vapor processors used
to meet the 80 mg/l standard for bulk terminal loading racks. After
consideration of the public comments, we have decided to include
presence of flame monitoring (as was proposed) for thermal oxidizers,
and vacuum level monitoring for carbon adsorbers, as alternatives for
monitoring the performance of vapor processors. We also took comments
and requested data on additional requirements for these alternative
monitoring approaches. We have incorporated these additional periodic
equipment and maintenance inspections of the vapor processor systems
into the final rule.
No major changes since proposal have been made to the requirements
for pipeline facilities or bulk plants.
For GDF (40 CFR part 63, subpart CCCCCC), we have incorporated
changes to the submerged fill requirements and the vapor balance
requirements on which we requested comments. The final rule contains
specific requirements for GDF nationwide depending on the GDF's monthly
gasoline throughput. All GDF, regardless of size, must implement
management practices that will minimize vapor releases to the
atmosphere. GDF with a monthly gasoline throughput of 10,000 gallons or
more must also use submerged fill when loading their storage tanks. In
addition to the requirements described above, GDF with a monthly
gasoline throughput of 100,000 gallons or more must use vapor balancing
when loading the storage tank. Subpart CCCCCC also contains
requirements applicable to gasoline cargo tanks.
IV. Additional Actions
In today's final rulemaking, we are also finalizing two additional
actions that were announced at proposal. These final actions address
title V permit requirements and our decision not to regulate the
gasoline distribution (Stage I) area source category under CAA section
112(c)(6).
A. Title V Permitting Requirements
Section 502(a) of the CAA provides that EPA may exempt one or more
area source categories from the requirements of title V if the
Administrator finds that compliance with such requirements is
``impracticable, infeasible, or unnecessarily burdensome'' on such
categories. EPA must determine whether to exempt an area source from
title V at the time we issue the relevant CAA section 112 standard (40
CFR 70.3(b)(2)). In this action, we are finalizing the proposed
exemption of gasoline distribution area sources from the requirement to
apply for and obtain a title V permit as a result of being subject to
these final rules. We justified this finding at proposal and did not
receive any negative comments during the public comment period
regarding this issue. In fact, we received two positive comments
supporting the exemption. As a result, gasoline distribution area
sources are not required to obtain title V permits because of being
subject to these final rules. However, if such sources are otherwise
required to obtain title V permits, e.g., due to being part of a major
source defined under title V (40 CFR 70.2, 40 CFR 71.2, and 40 CFR
63.2), they must apply for and obtain title V permits. The
applicability criteria for title V are in 40 CFR 70.3(a) and (b) and 40
CFR 71.3(a) and (b). We are adding additional regulatory text to this
rule to clarify the above.
B. Not Regulating This Source Category Under CAA Section 112(c)(6)
On November 8, 2002 (67 FR 68124), the Gasoline Distribution (Stage
I) Area Source category was added to the list of source categories for
development of standards under CAA section 112(c)(6) toward the 90-
percent requirement for polycyclic organic matter (POM). One
[[Page 1920]]
surrogate for POM is the sum of 16 polynuclear aromatic hydrocarbon
compounds (16-PAH) measured in EPA Test Method 610. Naphthalene is the
only 16-PAH estimated and reported in the 1990 inventory that is
emitted from gasoline distribution facilities. As explained in the
proposal preamble, we have revised the 1990 inventory of naphthalene
from this source category downward based on additional data received.
Based on that information, we have concluded that gasoline distribution
facilities (area sources) contribute only 0.02 percent of the total 16-
PAH (1.73 tons out of 8,051 tons) and are not needed to meet the 90-
percent requirement for POM in CAA section 112(c)(6). This action
finalizes our decision not to regulate this source category under CAA
section 112(c)(6) since we fully justified this conclusion at proposal
and did not receive any negative comments at proposal.
V. Summary of Comments and Responses
The gasoline distribution area source rules were proposed on
November 9, 2006 (71 FR 66064). The 60-day public comment period ended
on January 8, 2007, and we received 36 comment letters. Comments were
received from industry representatives, trade associations, State and
local air pollution control agencies, environmental groups, air
pollution control device vendors, and private citizens. The final rules
reflect our consideration of all of the comments received on the
proposed action. This section summarizes the significant comments and
those that resulted in changes in the final rules. Our responses to
comments not specifically addressed in this preamble are presented in
the Response to Comments Document, which is available in Docket No.
EPA-HQ-OAR-2006-0406.
A. Applicability
1. Area Sources
Comment: One commenter questioned whether EPA intended the area
source rules to apply to facilities that are major sources and that
have GDF on site for refueling of their vehicles (fleet vehicle
refueling centers). Another commenter stated that EPA should clarify
that the proposed rule does not apply to gasoline distribution major
sources.
Response: The gasoline distribution (Stage I) area source rules
apply to those gasoline distribution facilities that qualify as area
sources. Facilities that are major sources (emit >= 10 tons per year of
one HAP or emit >= 25 tons per year of any combination of HAP) as a
result of their gasoline distribution activities, or as a result of any
other activities, would not be subject to these final area source
rules. We have clarified in the final rules that these rules only apply
to area sources.
2. GACT Versus MACT Approach
Comment: One commenter stated that EPA's own interpretation of CAA
section 112(d)(5) allowed it to set GACT standards ``when the
imposition of MACT is determined to be unreasonable,'' (60 FR 4948,
4953, January 25, 1995) and that because EPA did not offer any
technological or economic reasons why MACT was unreasonable for this
source category, the selection of GACT rather than MACT was arbitrary
and capricious.
Response: EPA disagrees with the commenter's assertion. The
commenter has taken the phrase cited above in a prior Federal Register
notice out of context and erroneously asserts that EPA must first
justify why it is not setting a MACT standard before it can issue a
GACT standard for a particular area source category.
In the Federal Register notice cited above, EPA promulgated final
rules limiting the discharge of chromium compound emissions from both
major sources and area sources in the hard chromium electroplating,
decorative chromium electroplating and chromium anodizing tanks source
categories. In developing that rulemaking, we first established the
MACT standards for the major sources in each source category. Once we
determined the standards for major sources, which must be based on
MACT, we then evaluated what the standards should be for area sources.
At that time, EPA recognized that it had authority to issue GACT
standards for area sources. In determining what was GACT for those area
sources, EPA considered the standards it had just set for the major
sources and evaluated the technical feasibility of imposing the major
source requirements on the area sources.
Additionally, since EPA could consider cost in setting a GACT
standard, EPA also evaluated whether the cost of imposing the major
source standards on the area sources in those source categories would
be reasonable. The statements in the prior Federal Register notice
concerning CAA section 112(d)(5) were focused on the factual
circumstances of that rule, which involved the simultaneous
promulgation of major and area source standards. We did not, in that
rulemaking, conduct a thorough analysis of the requirements for setting
a GACT standard under CAA section 112(d)(5).
As recognized in the Federal Register notice cited above, and in
this final rule, Congress gave EPA explicit authority to issue
alternative emission standards for area sources in section 112(d)(5) of
the CAA. Specifically, CAA section 112(d)(5), which is entitled
``Alternative standard for area sources,'' provides:
With respect only to categories and subcategories of area
sources listed pursuant to subsection (c) of this section, the
Administrator may, in lieu of the authorities provided in paragraph
(2) and subsection (f) of this section, elect to promulgate
standards or requirements applicable to sources in such categories
or subcategories which provide for the use of generally available
control technologies or management practices by such sources to
reduce emissions of hazardous air pollutants. (Emphasis added.)
There are two critical aspects to CAA section 112(d)(5). First, CAA
section 112(d)(5) applies only to those categories and subcategories of
area sources listed pursuant to CAA section 112(c). The commenter does
not dispute that EPA listed the Gasoline Distribution (Stage I) Area
Source category pursuant to CAA section 112(c)(3). Second, CAA section
112(d)(5) provides that for area sources listed pursuant to CAA section
112(c), EPA ``may, in lieu of '' the authorities provided in CAA
section 112(d)(2) and 112(f), elect to promulgate standards pursuant to
CAA section 112(d)(5). CAA Section 112(d)(2) provides that emission
standards established under that provision ``require the maximum degree
of reduction in emissions'' of HAP (also known as MACT). CAA Section
112(d)(3), in turn, defines what constitutes the ``maximum degree of
reduction in emissions'' for new and existing sources. See CAA section
112(d)(3).\4\ Webster's dictionary defines the phrase ``in lieu of'' to
mean ``in the place of'' or ``instead of.'' See Webster's II New
Riverside University (1994). Thus, CAA section 112(d)(5) authorizes EPA
to promulgate standards under CAA section 112(d)(5) that provide for
the use of generally available control
[[Page 1921]]
technologies or management practices (GACT), instead of issuing MACT
standards pursuant to CAA section 112(d)(2) and (d)(3). The statute
does not set any condition precedent for issuing standards under
section 112(d)(5) other than that the area source category or
subcategory at issue must be one that EPA listed pursuant to CAA
section 112(c), which is the case here.\5\
---------------------------------------------------------------------------
\4\ Specifically, section 112(d)(3) sets the minimum degree of
emission reduction that MACT standards must achieve, which is known
as the MACT floor. For new sources, the degree of emission reduction
shall not be less stringent than the emission control that is
achieved in practice by the best-controlled similar source, and for
existing sources, the degree of emission reduction shall not be less
stringent than the average emission limitation achieved by the best-
performing 12 percent of the existing sources for which the
Administrator has emissions information. CAA section 112(d)(2)
directs EPA to consider whether more stringent--so called beyond-
the-floor limits--are technologically achievable considering, among
other things, the cost of achieving the emission reduction.
\5\ CAA section 112(d)(5) also references CAA section 112(f).
See CAA section 112(f)(5) (entitled ``Area Sources'' and providing
that EPA is not required to conduct a review or promulgate standards
under CAA section 112(f) for any area source category or subcategory
listed pursuant to CAA section 112(c)(3) and for which an emission
standard is issued pursuant to CAA section 112(d)(5)).
---------------------------------------------------------------------------
The commenter argues that EPA must provide a rationale for why
issuing MACT standards for this area source category is
``unreasonable'' before it can issue GACT standards under CAA section
112(d)(5). The commenter is incorrect, however. Had Congress intended
that EPA first conduct a MACT analysis for each area source category,
and only if cost or some other reason made applying the MACT standard
``unreasonable'' for the category would EPA be able to issue a standard
under CAA section 112(d)(5), Congress would have stated so expressly in
CAA section 112(d)(5). Congress did not require EPA to conduct any MACT
analysis, floor analysis, or beyond-the-floor analysis before the
Agency could issue a CAA section 112(d)(5) standard. Rather, Congress
authorized EPA to issue GACT standards for area source categories
listed under CAA section 112(c)(3), and that is precisely what EPA has
done in this rulemaking.
Although EPA has no obligation to justify why it is issuing a GACT
standard for an area source category as opposed to a MACT standard, EPA
must set a GACT standard that is consistent with the requirements of
CAA section 112(d)(5) and have a reasoned basis for its GACT
determination. In determining what constitutes GACT for a particular
area source category, EPA evaluates the control technologies and
management practices that reduce HAP emissions that are generally
available for the area source category.\6\ The legislative history
supporting CAA section 112(d)(5) provides that EPA may consider costs
in determining what constitutes GACT for the area source category.\7\
EPA cannot consider cost in setting MACT floors, pursuant to CAA
section 112(d)(3). Area sources differ from major sources, which is why
Congress permitted EPA to consider costs in setting GACT standards for
area sources under CAA section 112(d)(5), but did not permit that
consideration in setting MACT floors for major sources. This important
dichotomy between CAA section 112(d)(3) and CAA section 112(d)(5)
provides further evidence that Congress sought to do precisely what the
title of CAA section 112(d)(5) states--provide EPA the authority to
issue ``[a]lternative standards for area sources.'' EPA properly issued
standards for this area source category under CAA section 112(d)(5),
and as demonstrated below, EPA has a reasoned basis for each of its
GACT determinations.
---------------------------------------------------------------------------
\6\ As explained above, in developing GACT for the area sources
subject to this rule, EPA analyzed both the control technologies and
management practices used by area sources in the category to reduce
HAP and the control approaches employed by the major sources in this
category to reduce HAP.
\7\ Additional information on the definition of ``generally
available control technology or management practices'' (GACT) is
found in the Senate report on the 1990 amendments to the CAA (S.
Rep. No. 101-228, 101st Cong. 1st session, 171-172). That report
states that GACT is to encompass:
* * * Methods, practices, and techniques which are commercially
available and appropriate for application by the sources in the
category considering economic impacts and the technical capabilities
of the firms to operate and maintain the emissions control systems.
---------------------------------------------------------------------------
Finally, even accepting, for arguments sake, the commenter's
assertion that EPA must provide a rational basis for setting a GACT
standard as opposed to a MACT standard, we did so in the proposed rule.
In the proposal, we explained that we can and do consider costs and
economic impacts in determining GACT. We also explained that the
facilities in the source categories at issue here are already well
controlled for the Urban HAP for which the source category was listed
pursuant to CAA section 112(c)(3). We believe the consideration of
costs and economic impacts is especially important for the well-
controlled facilities in this area source category because, given
current well-controlled levels, a MACT floor determination, where costs
cannot be considered, could result in only marginal reductions in
emissions at very high costs for modest incremental improvement in
control for this area source category.
Comment: One commenter encouraged EPA to reevaluate GACT based on
the cost-effectiveness of controls for volatile organic compounds (VOC)
as a function of the source's throughput instead of using the cost-
effectiveness of controls for benzene. The commenter believes doing so
would demonstrate that more stringent emission standards and monitoring
requirements (similar to the MACT) are warranted for all but the
smallest of facilities. The commenter pointed out that in 1980, when
EPA developed the Control Technique Guidelines (CTG) for VOC control in
ozone non-attainment areas, $2,000 per ton was considered reasonably
available control technology (RACT). With inflation over the past 26
years, it should be in the range of $6,000 per ton. According to the
commenter, since benzene constitutes only about 1 percent of the VOC
emissions, the cost-effectiveness of these controls for VOC will be
about 100 times better. The commenter prefers applicability thresholds
based on throughput, rather than geographical boundaries, as proposed.
The commenter believes that the proposed GACT neglects consideration of
the risk posed by individual sources to the local communities. The
commenter also encouraged EPA to consider more stringent requirements
for ``new sources.''
Another commenter pointed out that, in addition to benzene
exposure, VOC from gasoline fueling play a role in the formation of
ground level ozone (smog). The commenter stated that EPA should
consider the full scope of air pollution concerns that are affected by
emissions from gasoline distribution and should design its Stage I
regulations to maximize the amount of reductions achieved for both air
toxics and ozone precursor emissions.
Response: We understand the commenters' desires for achieving
greater VOC emission reductions in this rulemaking. We agree that VOC
emissions contribute to other air pollution concerns and appreciate the
State and local agencies' efforts in addressing these emissions through
their regulatory programs. We also agree that an analysis of the
impacts of this rule based strictly on the control of VOC would yield
different cost-effectiveness values and potentially support requiring
more stringent control technologies for these facilities. In fact, we
did calculate VOC impacts during our analysis of the proposed and final
regulatory alternatives and these values are presented in the
supporting documentation. But, as explained in other sections of this
preamble, the primary focus of these area source rules is fulfilling
our obligations under CAA section 112(c)(3) for regulating stationary
sources of benzene. While the controls finalized today will achieve
reductions in both HAP and VOC emissions, we appropriately focused on
the HAP cost-effectiveness values in determining what is GACT for
facilities in this area source category.
Based on comments received, we have reconsidered the use of
gasoline throughput for determining what is GACT for these facilities
and have
[[Page 1922]]
incorporated multiple throughputs into the final rules. The final rules
require controls at affected facilities nationwide, thus, addressing
the impacts of benzene emissions from this area source category
regardless of geographical boundaries.
In the final rules we distinguish between new and existing sources
for the submerged fill requirements applicable to bulk gasoline plants
and GDF. See 40 CFR 63.11086, 40 CFR 63.11117, and 40 CFR 63.11118 for
the specific requirements. Control requirements at the remaining
facilities (bulk gasoline terminals, pipeline breakout stations, and
pipeline pumping stations) apply equally to both new and existing
sources.
3. Proposed Exemptions
Comment: One commenter stated that CAA section 112(d)(5) does not
authorize EPA to base GACT decisions on whether it believes that
control technologies are or are not cost-effective but, rather,
intended EPA to consider ``economic impacts.'' Therefore, EPA's
decision not to require a control level of 35 mg/l for loading racks,
1-inch pressure drop testing for cargo tanks, and vapor balancing of
storage tanks at bulk plants and GDF, based on cost-effectiveness
rather than technological or economic impact issues, is unlawful.
Response: We disagree with the commenter's interpretation that CAA
section 112(d)(5) does not authorize EPA to consider cost-effectiveness
as well as economic impacts in determining what is GACT for the
affected facilities in an area source category. The legislative history
supporting CAA section 112(d)(5) provides that EPA may consider costs
in determining what constitutes GACT for the area source category (see
footnote 7). Area sources differ from major sources, which is why
Congress permitted EPA to consider costs, including cost-effectiveness,
in setting GACT standards for area sources under CAA section 112(d)(5),
but did not permit that consideration in setting MACT floors for major
sources. The commenter did not cite any specific language in the CAA
that prevents us from considering cost-effectiveness as well as other
economic impacts in determining the level of control that constitutes
GACT for an area source category. We believe EPA properly considered
cost-effectiveness in each of its GACT determinations for this area
source category under CAA section 112(d)(5). See also Husqvarna AB v.
EPA, 349 U.S. App. D.C. 118, 254 F.3d 195, 201 (DC Cir. 2001) (finding
EPA's decision to consider costs on a per ton of emissions removed
basis reasonable because CAA section 213 did not mandate a specific
method of cost analysis).
Comment: One commenter stated that because the CAA requires
standards for all sources in a category, EPA's refusal to set standards
for storage tanks with a capacity less than 20,000 gallons is unlawful.
The commenter stated that EPA does not claim that no control technology
is generally available for storage tanks with a capacity less than
20,000 gallons or provide any reason that they cannot employ the same
technology that is used by larger storage tanks.
Response: In response to this comment, EPA reexamined its GACT
determination for storage tanks with a capacity less than 20,000
gallons. As explained above, determining what constitutes GACT involves
considering the control technologies and management practices that are
generally available to the facilites in the area source category. We
also consider standards applicable to major sources in the same
industrial sector to determine if the control technologies and
management practices are transferable and generally available to area
sources. We further consider the costs and economic impacts of
available control technologies and management practices on that source
category.
In the proposed and final rule, we distinguished storage tanks
based on size and developed a 20,000 gallon capacity threshold. This
size threshold is similar to the threshold used in several other
standards that apply to storage tanks, including 40 CFR part 60,
subpart Kb and the Gasoline Distribution Major Source NESHAP. As
explained in the 1994 ``Alternative Control Techniques Document:
Volatile Organic Liquid Storage in Floating and Fixed Roof Tanks''
(EPA-453/R-94-001), 20,000 gallons is generally considered to be the
breakpoint between horizontal and vertical tanks. The document reports
that most storage tanks below 20,000 gallons are horizontal rather than
vertical and a large percentage of these tanks are also underground
tanks.
In the final rule, we are requiring storage tanks with a capacity
of 20,000 gallons or more to have floating roof and seal technologies.
In response to this comment, we re-evaluated the application of these
same controls on tanks with a capacity less than 20,000 gallons and
determined that these control approaches do not represent GACT for
tanks with a capacity less than 20,000 gallons. First, for horizontal
tanks, which are generally tanks with a capacity below 20,000 gallons,
the floating roof technology is not technically feasible. Horizontal
tanks do not have perpendicular sides; this precludes the application
of floating roof technology to these tanks. Second, our analysis shows
that the cost-effectiveness of requiring the application of floating
roof technology to vertical storage tanks below the 20,000 gallon size
is, at best, about $8,000 per ton of HAP.
Instead, in the final rule, we are requiring that facilities using
storage tanks with a capacity below 20,000 gallons follow certain
management practices for controlling emissions. See 40 CFR 63.11087 for
those specific requirements.
Comment: One commenter believes it is not necessary to regulate GDF
that are already using submerged fill, especially when required by an
enforceable State, local, or tribal rule or permit. The commenter
believes that facilities already have safety, economic, and
environmental reasons to minimize spills, clean them up quickly, and
prevent gasoline from remaining in the environment; thus, according to
the commenter, additional emission reductions achieved by including
these management practices in the final rule might not be significant.
The commenter recommends that EPA evaluate the potential for emission
reductions achievable by requiring these management practices and, if
minimal emission reductions would result, EPA could either entirely
exclude tanks already equipped with a submerged fill system, or exclude
tanks covered by a submerged fill requirement in an enforceable State,
local, or tribal rule or permit. In either case, the commenter suggests
that the provision in the proposed 40 CFR 63.11085(f) would become an
exclusion in the proposed 40 CFR 63.11081.
Another commenter believes that GDF should be excluded from any and
all proposed and final regulatory alternatives because most States/
regions with unacceptable levels of VOC and HAP already require Stage I
controls which include submerged filling of underground storage tanks.
The commenter believes that including GDF in the applicability of the
proposed rule will inordinately increase the amount of paperwork
(requiring the submittal of Initial Notifications and Notification of
Compliance Status to dozens of States and local agencies) with little
to no environmental benefit. The commenter believes that GDF should be
regulated at the State and local level as they are today.
Response: By suggesting that we should not set Federal emission
[[Page 1923]]
standards, the commenters ignore the language of the statute. The CAA
requires that EPA set Federal emission standards under CAA section
112(d) for source categories listed under CAA section 112(c)(3), and
that is precisely what we are doing here. GDF are affected facilities
within the gasoline distribution (Stage I) area source category. These
facilities formed part of the basis for listing this area source
category; hence, EPA is promulgating rules regulating emissions from
these facilities. As summarized in section III.B of this preamble, 40
CFR part 63, subpart CCCCCC requires controls at GDF nationwide
depending on their monthly gasoline throughput. All GDF must employ
certain management practices. GDF with monthly throughput of 10,000
gallons or more must use submerged fill when loading their storage
tanks. GDF with a monthly throughput of 100,000 gallons or more must
also install a vapor balance system. These controls are GACT for these
facilities in this area source category.
We agree with the concept of reducing the reporting and
recordkeeping burden on affected facilities. We have taken steps in the
proposed and final rules to minimize these burdens by not requiring
notifications or reports from facilities that are already operating in
compliance with enforceable State, local, or tribal rules and permits
that include requirements that are at least as stringent as those
contained in these final rules.
Comment: Two commenters support exempting bulk plants and pipeline
pumping facilities because emissions from pipeline pumping stations are
insignificant and because the recordkeeping and reporting would
represent a burden with no benefit. The commenters stated that if EPA
does not agree to fully exempt bulk plants and pipeline pumping
stations, at the very least, those facilities that do not have a
storage tank or loading rack subject to controls should be exempted
from the equipment leak requirements.
Response: As explained above, by suggesting that we should not set
Federal emission standards for these facilities, the commenters ignore
the language of the statute. The CAA requires that EPA set Federal
emission standards under CAA section 112(d) for source categories
listed under CAA section 112(c)(3), and that is precisely what we are
doing here. Bulk plants and pipeline pumping stations are affected
facilities within the Gasoline Distribution (Stage I) Area Source
category. These facilities formed part of the basis for listing this
area source category; hence, EPA is promulgating rules regulating
emissions from these facilities. As such, 40 CFR part 63, subpart
BBBBBB includes requirements for controls at these facilities based on
what EPA determined was GACT for each facility.
We have, however, taken steps to reduce the reporting and
recordkeeping burden on these facilities. The requirement to submit a
combined Initial Notification/Notification of Compliance Status is the
only routine reporting requirement imposed on these facilities. No
periodic reports are required as part of the equipment leak inspection
program as long as leaks are repaired in a timely manner. We believe
that the potential safety and environmental benefits of an equipment
leak inspection program justify the minimal expense involved.
4. Nationwide Coverage Versus Urban Area Coverage for Standards
Comment: Several commenters stated that they were strongly opposed
to EPA's intended approach to narrow the application of CAA section
112(d) area source rules to urban areas, while other commenters were
opposed to broadening the applicability of the rules to all areas.
One commenter stated that because CAA section 112 does not
authorize EPA to decline to set standards for any sources within a
category of sources that it has listed pursuant to CAA section 112(c),
the threshold for sources that are not in urban areas (as well as those
below the proposed size applicability thresholds) would be unlawful.
One commenter stated that there is little justification apparent in
the proposed rule for mandating submerged fill for loading of storage
tanks in non-urban areas. The commenter claimed that to do so would
result in additional costs to GDF, while achieving minimal reductions
in emissions. The commenter stated that, as a matter of law, the
Agency's discretion is limited to imposing area source controls to area
sources located within urban areas.
One commenter believes that EPA should apply the rule in accordance
with the expressed intent of Congress, which was to reduce ``risks to
public health in urban areas.'' Therefore, according to this commenter,
the rule should apply only to facilities that are located in or near
urban areas. The commenter also stated that health risk should be taken
into account in evaluating cost-effectiveness, and risk-distance issues
should be considered. The commenter provided an analysis of their
recommended use of a risk-distance look-up table to determine
applicability of the rule.
Other commenters stated that regardless of whether residential
populations are urban or rural, individuals living in close proximity
to GDF are subjected to elevated exposures to HAP and, given the trend
of building very high volume throughput GDF, the level of exposure is
likely to remain high and even increase.
One commenter urged EPA to follow conventional approaches in
determining the scope of controls, and, in so doing, apply proposed
Regulatory Alternatives (RA) 2 and 3 to all counties nationwide. The
commenter urges EPA in this rulemaking, and in future area source
rulemakings, to apply area source standards uniformly in all counties
nationwide, particularly in circumstances where the area source
category is ubiquitous, as is the case with gasoline distribution.
Another commenter stressed that the impacts of emissions from
gasoline distribution and dispensing facilities are localized and would
be similar for most urban and rural areas. The commenter stated that
the cost of controlling these facilities would be the same in rural or
urban settings as well; therefore, because the costs and environmental
impacts are the same, there does not appear to be any rationale for
treating rural and urban facilities differently.
One commenter stated that the fact that some State and local
agencies already regulate these sources does not relieve EPA of its
obligation to reduce emissions under CAA section 112. According to
another commenter, many State and local agencies cannot be more
stringent than the Federal government. The commenter further stated
that once a Federal rule is promulgated, some agencies must change
their regulations to make them consistent with those of the Federal
government, which could result in backsliding if the State or local
rule was more stringent to begin with.
Two comments expressed opposition to limiting the geographic scope
of the proposed regulatory alternatives to reduce the ``overall cost of
the rule.''
Response: After consideration of all comments related to the issue
of nationwide versus urban applicability of the proposed standards for
submerged fill and vapor balancing at GDF (proposed RA 2 and 3), we
believe a nationwide approach is appropriate given the facts and
circumstances of this particular area source category. As suggested by
commenters, the final rule requires GDFs nationwide to control HAP
emissions, and those control requirements differ depending on the
monthly throughput of the GDF, which
[[Page 1924]]
is a reasonable factor for distinguishing between GDF. As explained in
other responses and sections of this preamble, the final rule requires
all GDF, regardless of size, to implement certain management practices
to reduce vapor evaporation. Additionally, GDF with a monthly
throughput of 10,000 gallons or more must use submerged fill, while GDF
with a monthly throughput of 100,000 gallons or more must install vapor
balance systems.
As proposed, the rule would have only required controls at GDF
located in Urban 1 and Urban 2 areas. Some commenters suggested further
narrowing the applicability of the rule to GDF based on the health
risks and distance to the population of individual facilities. However,
facilities located in Urban 1 and Urban 2 areas were the basis for
listing area source categories pursuant to section 112(c)(3) of the
CAA. We are currently under court-ordered deadlines to complete issuing
standards for all listed area source categories. Changing our focus
would mean recreating an area source category list which may differ
significantly from the current list, greatly hindering our effort to
complete our obligation by the court-ordered deadlines. Therefore, we
believe that revisiting the basis for listing the area source
categories is inappropriate at this time. And, as further explained
below, we believe the particular facts for this area source category
indicate that GDF nationwide should implement controls based on their
monthly gasoline throughput.
We believe that the CAA provides the Agency with the authority to
regulate area sources nationwide. As explained in the Strategy and the
proposed rule, we interpret these provisions as providing EPA authority
to regulate listed area source categories on a nationwide basis.
Indeed, in several other area source rules, EPA has exercised this
discretion and issued rules of nationwide applicability, as it has done
here. See, e.g., 72 FR 26 (January 3, 2007); 72 FR 2930 (January 23,
2007); 72 FR 38864 (July 16, 2007).
A rule of nationwide applicability is particularly appropriate here
because control costs are not expected to differ in rural vs. urban
settings, so the control's cost-effectiveness is the same, and economic
impacts are equally distributed. In addition, after reviewing the
public comments and the additional analyses presented in support of
those comments, we determined that the controls discussed above are
commercially available as they are being used by many bulk facilities
and GDF, and they are cost-effective (considering the source type and
size thresholds noted above) for bulk facilities and GDF.
Therefore, consistent with CAA section 112(d)(5), the final rule
establishes standards that reflect the application of generally
available control technology or management practices, and we properly
considered cost-effectiveness and other economic impacts in determining
what constitutes GACT for this area source category.
The commenter also suggested that we should consider health risks
in making our GACT determination for each facility. In the 1990 CAA
Amendments, Congress established a two-phase approach for setting HAP
emission standards. Sierra Club v. EPA, 353 F.3d 976, 980 (DC Cir.
2004). The first phase is the initial standard setting phase, which is
the pha