[Federal Register Volume 75, Number 201 (Tuesday, October 19, 2010)]
[Proposed Rules]
[Pages 64221-64235]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2010-26262]
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ENVIRONMENTAL PROTECTION AGENCY
40 CFR Part 49
[EPA-R09-OAR-2010-0683; FRL-9213-7]
Source Specific Federal Implementation Plan for Implementing Best
Available Retrofit Technology for Four Corners Power Plant: Navajo
Nation
AGENCY: Environmental Protection Agency (EPA).
ACTION: Proposed rule.
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SUMMARY: The Environmental Protection Agency (EPA) is proposing to
promulgate a source specific Federal Implementation Plan (FIP)
requiring the Four Corners Power Plant (FCPP), located on the Navajo
Nation, to achieve emissions reductions required by the Clean Air Act's
Best Available Retrofit Technology (BART) provision. In this action,
EPA is proposing to require FCPP to reduce emissions of oxides of
nitrogen (NOX) and particulate matter (PM). These pollutants
are significant contributors to visibility impairment in the numerous
mandatory Class I Federal areas surrounding FCPP. For NOX
emissions, EPA is proposing to require FCPP to meet an emission limit
of 0.11 lb/MMBtu, representing an 80% reduction from current
NOX emissions. This NOX limit is achievable by
installing and operating Selective Catalytic Reduction (SCR) technology
on Units 1-5. For PM, EPA is proposing to require FCPP to meet an
emission limit of 0.012 lb/MMBtu for Units 1-3 and 0.015 lb/MMBtu for
Units 4 and 5. These emissions limits are achievable by installing and
operating any of several equivalent controls on Units 1-3, and through
proper operation of the existing baghouse on Units 4 and 5. EPA is
proposing to require FCPP to meet a 10% opacity limit on Units 1-5 to
ensure proper operation of the PM controls. EPA is requesting comment
on whether APS can satisfy BART on Units 1-3 by operating the existing
venturi scrubbers to meet an emission limit of 0.03 lb/MMBtu with a 20%
opacity limit. EPA is also proposing to require FCPP to comply with a
20% opacity limit on its coal and material handling operations.
DATES: Comments must be submitted no later than December 20, 2010.
ADDRESSES: Submit comments, identified by docket number EPA-R09-OAR-
2010-0683, by one of the following methods:
Federal eRulemaking Portal: http://www.regulations.gov. Follow the
on-line instructions.
E-mail: [email protected].
Mail or deliver: Anita Lee (Air-3), U.S. Environmental Protection
Agency Region IX, 75 Hawthorne Street, San Francisco, CA 94105-3901.
Instructions: All comments will be included in the public docket
without change and may be made available online at http://www.regulations.gov, including any personal information provided,
unless the comment includes Confidential Business Information (CBI) or
other information whose disclosure is restricted by statute.
Information that you consider CBI or otherwise protected should be
clearly identified as such and should not be submitted through http://www.regulations.gov or e-mail. http://www.regulations.gov is an
``anonymous access'' system, and EPA will not know your identity or
contact information unless you provide it in the body of your comment.
If you send e-mail directly to EPA, your e-mail address will be
automatically captured and included as part of the public comment. If
EPA cannot read your comment due to technical difficulties and cannot
contact you for clarification, EPA may not be able to consider your
comment.
Hearings: EPA intends to hold public hearings in two locations in
New Mexico to accept oral and written comments on the proposed
rulemaking. EPA anticipates these hearings will occur in Shiprock and
Farmington. EPA will provide notice and additional details at least 30
days prior to the hearings in the Federal Register, on our Web site,
and in the docket.
Docket: The index to the docket for this action is available
electronically at http://www.regulations.gov and in hard copy at EPA
Region IX, 75 Hawthorne Street, San Francisco, California. While all
documents in the docket are listed in the index, some information may
be publicly available only at the hard copy location (e.g., copyrighted
material), and some may not be publicly available in either location
(e.g., CBI). To inspect the hard copy materials, please schedule an
appointment during normal business hours with the contact listed in the
FOR FURTHER INFORMATION CONTACT section.
FOR FURTHER INFORMATION CONTACT: Anita Lee, EPA Region IX, (415) 972-
3958, [email protected].
SUPPLEMENTARY INFORMATION: Throughout this document, ``we'', ``us'',
and ``our'' refer to EPA.
Table of Contents
I. Background
A. Statutory and Regulatory Framework for Addressing Visibility
B. Statutory and Regulatory Framework for Addressing Sources
Located in Indian Country
C. Statutory and Regulatory Framework for BART Determinations
D. Factual Background
1. Four Corners Power Plant
2. Relationship of NOX and PM to Visibility
Impairment
II. EPA's Proposed Action Based on Five Factors Test
A. A BART Determination for FCPP Is Necessary or Appropriate
B. Summary of Proposed BART Emission Limits
C. Available and Feasible Control Technologies and Five Factor
Analysis for NOX Emissions
i. Factor 1: Cost of Compliance
ii. Factor 2: Energy and Non-Air Quality Impacts
iii. Factor 3: Existing Controls at the Facility
iv. Factor 4: Remaining Useful Life of Facility
v. Factor 5: Degree of Visibility Improvement
D. Available and Feasible Control Technologies and Five Factor
Analysis for PM Emissions
i. Factor 1: Cost of Compliance
ii. Factor 2: Energy and Non-Air Quality Impacts
iii. Factor 3: Existing Controls at the Facility
iv. Factor 4: Remaining Useful Life of Facility
v. Factor 5: Degree of Visibility Improvement
III. EPA's Proposed Action on Material Handling Limits
IV. Administrative Requirements
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
[[Page 64222]]
I. National Technology Transfer and Advancement Act
J. Executive Order 12898: Federal Actions To Address
Environmental Justice in Minority Populations and Low-Income
Populations
I. Background
A. Statutory and Regulatory Framework for Addressing Visibility
Part C, Subpart II, of the Act, establishes a visibility protection
program that sets forth ``as a national goal the prevention of any
future, and the remedying of any existing, impairment of visibility in
mandatory class I Federal areas which impairment results from manmade
air pollution.'' 42 U.S.C. 7491A(a)(1). The terms ``impairment of
visibility'' and ``visibility impairment'' are defined in the Act to
include a reduction in visual range and atmospheric discoloration. Id.
7491A(g)(6). A fundamental requirement of the visibility protection
program is for EPA, in consultation with the Secretary of the Interior,
to promulgate a list of ``mandatory Class I Federal areas'' where
visibility is an important value. Id. 7491A(a)(2). These areas include
national wilderness areas and national parks greater than six thousand
acres in size. Id. 7472(a).
On November 30, 1979, EPA identified 156 mandatory Class I Federal
areas where visibility is an important value, including for example:
Grand Canyon National Park in Arizona (40 CFR 81.403); Mesa Verde
National Park and La Garita Wilderness Area in Colorado (Id. 81.406);
Bandelier Wilderness Area in New Mexico (Id. 81.421); and Arches, Bryce
Canyon, Canyonlands and Capitol Reef National Parks in Utah (Id.
81.430). These mandatory Class I Federal areas are within an
approximately 300 km (or 186 mile) radius of FCPP.
On December 2, 1980, EPA promulgated the first phase of the
required visibility regulations, codified at 40 CFR 51.300-307. 45 FR
80084. The 1980 regulations deferred regulating regional haze from
multiple sources finding that the scientific data were inadequate at
that time. Id. at 80086.
Congress added Section 169B to the Act in the 1990 CAA Amendments,
requiring EPA to take further action to reduce visibility impairment in
broad geographic regions. 42 U.S.C. 7492. In 1993, the National Academy
of Sciences released a comprehensive study required by the 1990
Amendments concluding that ``current scientific knowledge is adequate
and control technologies are available for taking regulatory action to
improve and protect visibility.'' Protecting Visibility in National
Parks and Wilderness Areas, Committee on Haze in National Parks and
Wilderness Areas, National Research Council, National Academy Press
(1993).
EPA promulgated regulations to address regional haze on April 22,
1999. 64 FR 35765. Consistent with the statutory requirement in 42
U.S.C. 7491(b)(2)(a), EPA's 1999 regional haze regulations include a
provision requiring States to require certain major stationary sources
``in existence on August 7, 1977, but which ha[ve] not been in
operation for more than fifteen years as of such date'' which emit
pollutants that are reasonably anticipated to cause or contribute to
any visibility impairment to procure, install and operate BART. In
determining BART, States are required to take into account five factors
identified in the CAA and EPA's regulations. 42 U.S.C. 7491(g)(2) and
40 CFR 51.308.
B. Statutory and Regulatory Framework for Addressing Sources Located in
Indian Country
When the Clean Air Act was amended in 1990, Congress included a new
provision, Section 301(d), granting EPA authority to treat Tribes in
the same manner as States where appropriate. See 40 U.S.C. 7601(d).
Congress also recognized, however, that such treatment may not be
appropriate for all purposes of the Act and that in some circumstances,
it may be inappropriate to treat tribes identically to states.
Therefore, Section 301(d)(2) of the Act directed EPA to promulgate
regulations ``specifying those provisions of [the CAA] for which it is
appropriate to treat Indian tribes as States.'' Id. 7601(d)(2). In
addition, Congress provided that ``[i]n any case in which [EPA]
determines that the treatment of Indian tribes as identical to States
is inappropriate or administratively infeasible, the Administrator may
provide, by regulation, other means by which the Administrator will
directly administer such provisions so as to achieve the appropriate
purpose.'' Id. 7601(d)(4).
In 1998, EPA promulgated regulations at 40 CFR part 49 (which have
been referred to as the Tribal Authority Rule or TAR) relating to
implementation of CAA programs in Indian Country. See 40 CFR part 49;
see also 59 FR 43956 (Aug. 25, 1994) (proposed rule); 63 FR 7254 (Feb.
12, 1998) (final rule); Arizona Public Service Company v. EPA, 211 F.3d
1280 (DC Cir. 2000), cert. den., 532 U.S. 970 (2001) (upholding the
TAR). The TAR allows EPA to treat eligible Indian Tribes in the same
manner as States ``with respect to all provisions of the [CAA] and
implementing regulations, except for those provisions [listed] in 49.4
and the [EPA] regulations that implement those provisions.'' 40 CFR
49.3. EPA recognized that Tribes were in the early stages of developing
air planning programs known as Tribal Implementation Plans (TIPs) and
that Tribes would need additional time to develop air quality programs.
62 FR 7264-65. Thus, EPA determined that it was not appropriate to
treat Tribes in the same manner as States for purposes of those
provisions of the CAA imposing air program submittal deadlines. See 59
FR at 43964-65; 63 FR at 7264-65. Similarly, EPA determined that it
would be inappropriate to treat Tribes the same as States for purposes
of the related CAA provisions establishing sanctions and federal
oversight mechanisms where States fail to meet applicable air program
submittal deadlines. Id. Thus, one of the CAA provisions that EPA
determined was not appropriate to apply to Tribes is Section 110(c)(1).
See 40 CFR 49.4(d). In particular, EPA found that it was inappropriate
to impose on Tribes the provisions in Section 110(c)(1) for EPA to
promulgate a FIP within 2 years after a State fails to make a required
plan submission.
Although EPA determined that the requirements of CAA section
110(c)(1) were not applicable to Tribes, EPA also determined that under
other provisions of the CAA it has the discretionary authority to
promulgate ``such federal implementation plan provisions as are
necessary or appropriate to protect air quality'' when a Tribe has not
submitted a TIP. 40 CFR 49.11. EPA determined in promulgating the TAR
that it could exercise discretionary authority to promulgate FIPs based
on Section 301(a) of the CAA, which authorizes EPA to prescribe such
regulations as are necessary to carry out the Act, and Section
301(d)(4), which authorizes EPA to directly administer CAA provisions
for which EPA has determined it is inappropriate or infeasible to treat
Tribes as identical to States. 40 CFR 49.11. See also 63 FR at 7265.
Specifically, 40 CFR 49.11(a) provides that EPA shall promulgate
without unreasonable delay such Federal implementation plan provisions
as are necessary or appropriate to protect air quality, consistent with
the provisions of sections 301(a) and 301(d)(4), if a tribe does not
submit a tribal implementation plan or does not receive EPA approval of
a submitted tribal implementation plan.
EPA has previously promulgated FIPs under the TAR to regulate air
pollutants emitted from the two coal fired electric generating
facilities on the Navajo
[[Page 64223]]
Nation, FCPP and Navajo Generating Station (NGS). In 1991, EPA also
revised an existing FIP that applied to Arizona to include a
requirement for NGS to substantially reduce its SO2
emissions by installing scrubbers based on finding that the
SO2 emissions were contributing to visibility impairment at
the Grand Canyon National Park. 56 FR 50172 (Oct. 3, 1991); see also
Central Arizona Water Conservation District v. United States
Environmental Protection Agency, 990 F.2d 1531 (9th Cir. 1993).
In 1999, after several years of negotiations, EPA proposed
concurrent but separate FIPs for FCPP and NGS. Those FIPs proposed to
fill the regulatory gap that existed because permits and SIP rules by
New Mexico (for FCPP) and Arizona (for NGS) were not applicable or
enforceable on the Navajo Nation, and the Tribe had not sought approval
of a TIP covering the plants. 64 FR 48731 (Sept. 8, 1999).
Before EPA finalized the 1999 FIPs, the operator of FCPP began
negotiations to reduce SO2 emissions from FCPP by making
upgrades to improve the efficiency of its SO2 scrubbers. The
negotiations resulted in an agreement for FCPP to increase the
SO2 control from a 72% reduction of the potential
SO2 emissions to an 88% reduction. As a result of this
increased scrubber efficiency, FCPP's SO2 emissions
decreased by a total of 57% from the historical levels. The parties to
the negotiations requested EPA to make those SO2 reductions
enforceable through a source specific FIP. Therefore, EPA proposed new
FIPs for FCPP and NGS in September 2006. 71 FR 53631 (Sept. 12, 2006).
In these concurrent but separate FIPs, EPA proposed to make emissions
limits contained in State permits or rules that had previously been
followed by FCPP and NGS federally enforceable. In addition, for FCPP,
EPA proposed to establish a significantly lower SO2
emissions limit based on the increased scrubber efficiency, resulting
in a reduction of approximately 22,000 tons of SO2 per year.
EPA indicated in the final FIP for FCPP that the new SO2
emissions limits were close to or the equivalent of the emissions
reductions that would have been required in a BART determination. 72 FR
25698 (May 7, 2007). The FIP also required FCPP to comply with a 20%
opacity limit on both the combustion and fugitive dust emissions coal
handling operations. EPA finalized the FIP for FCPP in May 2007. Id.
APS, the operator of FCPP, and the Sierra Club each filed Petitions
seeking judicial review of EPA's promulgation of the 2007 FIP for FCPP,
on separate grounds. APS argued that EPA did not have authority to
promulgate a source-specific FIP for FCPP without its consent. APS also
argued that EPA did not have authority to promulgate a 20% opacity
standard on the combustion equipment unless we provided an exemption
for malfunctions. Finally, APS argued that EPA had not established an
adequate basis for requiring a 20% opacity limit on the fugitive dust
from the coal handling operations. In contrast, Sierra Club argued that
EPA could not promulgate a ``gap filling'' FIP that did not include
modeling and an analysis to show continued attainment of the NAAQS.
The Court of Appeals for the Tenth Circuit rejected both Petitions.
With respect to the Sierra Club's arguments, the Court considered the
regulatory language in 40 CFR 49.11(a) and concluded that ``[t]his
language does not impose upon the EPA the duty the Environmentalists
propose. It provides the EPA discretion to determine what rulemaking is
necessary or appropriate to protect air quality and requires the EPA to
promulgate such rulemaking.'' Arizona Public Service v. EPA, 562 F.3d
1116, 1125 (10th Cir. 2009). The Court also rejected arguments by APS
that EPA could not impose a continuous opacity limitation during
operations, provided EPA set forth a reasonable basis for its decision.
Id. at 1129 (``That APS does not agree with the EPA's rejection of the
substance of its proposed 0.2% allowance is irrelevant; as long as
EPA's decision making process may reasonably be discerned, we will not
set aside the federal plan on account of a less-than-ideal
explanation.'' [citation omitted]). The Court agreed with EPA's request
for a voluntary remand of the opacity limit for the fugitive dust for
the material handling operations and remanded that narrow aspect of the
2007 FIP. Id. at 1131.
The FIP that EPA is proposing today is promulgated under the same
authority in 40 CFR 49.11(a). EPA is proposing to find that it is
necessary or appropriate to establish BART requirements for
NOX and PM emissions from FCPP, and is proposing specific
NOX and PM limits as BART. EPA is proposing to establish a
10% opacity limit from Units 1-5 to ensure continuous compliance with
the PM emissions limit. EPA is also proposing a 20% opacity limit to
apply to FCPP's material handling operations in response to the remand
from the 2007 FIP.
C. Statutory and Regulatory Framework for BART Determinations
When Congress enacted Section 169A of the CAA to protect
visibility, it directed EPA to promulgate regulations that, inter alia,
would require applicable implementation plans to include a
determination of BART for certain major stationary sources. 42 U.S.C.
7491(b)(2)(A) & (g). These major stationary sources are fossil-fuel
fired steam electric plants of more than 250 MMBtu/hr heat input, kraft
pulp mills, Portland cement plants and other listed industrial sources
that came into operation between 1962 and 1977 and are ``reasonably
anticipated to cause or contribute to any impairment of visibility in
any [Class I area].'' Id. EPA guidelines must be followed in making
BART determinations for fossil fuel fired electric generating plants
larger than 750 MW. See 40 CFR Part 51, Appendix Y.
FCPP and NGS are the only eligible BART sources located on the
Navajo Nation. See Western Regional Air Partnership, http://www.wrapair.org/forums/ssjf/bart.html, XLS Spreadsheet, Line 184, 185,
Column N. An eligible BART source with a predicted impact of 0.5 dv or
more of impairment in a Class I area ``contributes'' to visibility
impairment and is subject to BART. 70 FR 39104, 39121 (July 6, 2005).
FCPP contributes to impairment at many surrounding Class I areas well
in excess of this threshold.
EPA's guidelines for evaluating BART for such sources are set forth
in Appendix Y to 40 CFR Part 51. See also 40 CFR 51.308(e)(1)(ii)(A).
Consistent with statutory and regulatory requirements, the Guidelines
require consideration of ``five factors'' in making BART
determinations. Id. at IV.A. Those factors, from the Act's statutory
definition of BART, which are applied to all technically feasible
control technologies, are: (1) The costs of compliance, (2) the energy
and non-air quality environmental impacts of compliance, (3) any
pollution control equipment in use or in existence at the source, (4)
the remaining useful life of the source, and (5) the degree of
improvement in visibility which may reasonably be anticipated to result
from the use of such technology. 40 CFR 51.308(e)(1)(ii)(A).
In this proposed action, EPA has taken into consideration each of
the five factors after identifying feasible control technologies for
FCPP's NOX and PM emissions.
[[Page 64224]]
D. Factual Background
1. Four Corners Power Plant
FCPP is a privately owned and operated coal-fired power plant
located on the Navajo Nation Indian Reservation near Farmington, New
Mexico. Based on lease agreements signed in 1960, FCPP was constructed
and has been operating on real property held in trust by the Federal
government for the Navajo Nation. The facility consists of five coal-
fired electric utility steam generating units with a total capacity of
2060 megawatts (MW). Units 1, 2, and 3 at FCPP are owned entirely by
Arizona Public Service (APS), which serves as the facility operator,
and are rated to 170 MW (Units 1 and 2) and 220 MW (Unit 3). Units 4
and 5 are each rated to a capacity of 750 MW, and are co-owned by six
entities: Southern California Edison (48%), APS (15%), Public Service
Company of New Mexico (13%), Salt River Project (SRP) (10%), El Paso
Electric Company (7%), and Tucson Electric Power (7%).
Based on 2009 emissions data from the EPA Clean Air Markets
Division,\1\ FCPP is the largest source of NOX emissions in
the United States (over 40,000 tons per year (tpy) of NOX).
FCPP, located near the Four Corners region of Arizona, New Mexico,
Utah, and Colorado, is approximately 300 kilometers (km) from sixteen
mandatory Class I Federal areas: Arches National Park (NP), Bandelier
National Monument (NM), Black Canyon of the Gunnison Wilderness Area
(WA), Canyonlands NP, Capitol Reef NP, Grand Canyon NP, Great Sand
Dunes NP, La Garita WA, Maroon Bells-Snowmass WA, Mesa Verde NP, Pecos
WA, Petrified Forest NP, San Pedro Parks WA, West Elk WA, Weminuche WA,
and Wheeler Park WA.
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\1\ ``Clean Air Markets--Data and Maps: http://camddataandmaps.epa.gov/gdm/.
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APS provided information relevant to a BART analysis to EPA on
January 29, 2008. The information consisted of a BART engineering and
cost analysis conducted by Black and Veatch (B&V) dated December 4,
2007 (Revision 3), a BART visibility modeling protocol prepared by ENSR
Corporation (now called AECOM and referred to as AECOM throughout this
document) dated January 2008, a BART visibility modeling report
prepared by AECOM dated January 2008, and a document titled APS BART
Analysis conclusions, dated January 29, 2008. APS provided supplemental
information on cost and visibility modeling in correspondence dated May
28, 2008, June 10, 2008, November 2008, March 16, 2009, October 29,
2009, and April 22, 2010. All of these documents are available in the
docket for this proposal.
2. Relationship of NOX and PM to Visibility Impairment
Particulate matter less than 10 microns (millionths of a meter) in
size (PM10) interacts with light. The smallest particles in
the 0.1 to 1 micron range interact most strongly as they are about the
same size as the wavelengths of visible light. The effect of the
interaction is to scatter light from its original path. Conversely, for
a given line of sight, such as between a mountain scene and an
observer, light from many different original paths is scattered into
that line. The scattered light appears as whitish haze in the line of
sight, obscuring the view.
PM emitted directly into the atmosphere, also called primary PM, is
emitted both from the boiler stacks and from material handling. Of
primary PM emissions, those in the smaller particle size range, less
than 2.5 microns, tend to have the most impact on visibility. PM
emissions from the boiler stacks can have varying particle size makeup
depending on the PM control technology. PM from material handling,
though, tends to be coarse, i.e. around 10 microns, since it is created
from the breakup of larger particles of soil and rock.
PM that is formed in the atmosphere from the condensation of
gaseous chemical pollutants, also called secondary PM, tends to be
fine, i.e. smaller than 1 micron, since it is formed from the buildup
of individual molecules. This secondary PM tends to contribute more to
visibility impairment than primary PM because it is in the size range
where it most effectively interacts with visible light. NOX
and SO2 emissions from coal fired power plants are two
examples of gaseous chemical pollutants that react with other compounds
in the atmosphere to form secondary PM. Specifically, NOX is
a gaseous pollutant that can be oxidized to form nitric acid. In the
atmosphere, nitric acid in the presence of ammonia forms particulate
ammonium nitrate. The formation of particulate ammonium nitrate is
dependent on temperature and relative humidity, and therefore, varies
by season. Particulate ammonium nitrate can grow into the size range
that effectively interacts with light by coagulating together and by
taking on additional pollutants and water. The same principle applies
to SO2 and the formation of particulate ammonium sulfate.
In air quality models, secondary PM is tracked separately from
primary PM because the amount of secondary PM formed depends on weather
conditions and because it can be six times more effective at impairing
visibility. This is reflected in the equation used to calculate
visibility impacts from concentrations measured by the Interagency
Monitoring of Protected Visual Environments (IMPROVE) monitoring
network covering Class I areas.\2\
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\2\ Guidance for Estimating Natural Visibility Conditions Under
the Regional Haze Rule, U.S. Environmental Protection Agency'', EPA-
454/B-03-005, September 2003; http://www.epa.gov/ttn/oarpg/t1pgm.html.
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II. EPA's Proposed Action on the Five Factor Test
A. A BART Determination for FCPP Is Necessary or Appropriate
The numerous Class I areas that surround FCPP are sometimes known
as the Golden Circle of National Parks. See http://www.nps.gov/history/history/online_books/nava/adhi/adhi4e.htm. Millions of tourists visit
these areas, many visiting from other countries to view the unique
vistas of the Class I areas in the Four Corners region.
As Congress recognized, visibility is an important value and must
be protected in these areas. Yet, air quality and visibility are
impaired in the 16 Class I areas surrounding FCPP. The National Park
Service noted in 2008 that ``[v]isibility is impaired to some degree at
all units where it is being measured and remains considerably higher
than the target national conditions in many places, particularly on the
haziest days.'' Air Quality in National Parks, 2008 Annual Performance
& Progress Report, National Resource Report NPS/NRPC/ARD/NRR-2009/151,
September 2009, p. 30. Mesa Verde, Grand Canyon, Bryce Canyon and
Canyonlands are among the areas the Park Service is monitoring. Id.
Table 3, p. 19. Although not directly related to visibility,
NOX is also a precursor to ozone formation and the National
Park Service also determined that ozone concentrations in Mesa Verde
appears to be trending upward over the 1994-2007 period and the Park's
annual 4th-highest 8-hour ozone concentrations ``are approaching the
[NAAQS] standard.'' Id. at 16. FCPP, which emitted over 42,000 tons of
NOX in 2009,\3\ was built roughly four decades ago and has
not installed any new NOX controls since the 1990's,
including modern combustion technology such as post-2000 low-
NOX burners (LNB) or separated overfire air.
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\3\ Clean Air Markets Division--Data--Maps.
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Based on the importance of visibility as a value in this Golden
Circle of
[[Page 64225]]
National Parks, and the substantial NOX and PM emissions
generated by operating FCPP, EPA is proposing to find that BART
emission limits are necessary or appropriate.
B. Summary of Proposed BART Emissions Limits
On August 28, 2009, EPA published an Advanced Notice of Proposed
Rulemaking (ANPRM) concerning two of the five factors in the BART
analysis: Cost of compliance and anticipated visibility improvement. 74
FR 44314. EPA received numerous comments on the ANPRM, including
comments from the Navajo Nation, APS, National Park Service and
environmental groups. EPA has considered relevant comments we received
on the ANPRM in determining which NOX and PM emission
limitations we are proposing today as BART for FCPP.
Based on the available control technologies and the five factors
discussed in more detail below, EPA is proposing to require FCPP to
meet a NOX emission limit on Units 1-5 of 0.11 lb/MMBtu. EPA
is proposing a PM emission limit on Units 1-3 of 0.012 lb/MMBtu and on
Units 4 and 5 of 0.015 lb/MMBtu as BART. EPA is taking comment on an
alternative PM emissions limit for Units 1-3 described in more detail
in Section II.D.
EPA is not proposing to require each unit to achieve the specified
NOX emission limit. EPA is proposing to require FCPP to meet
a plant-wide heat input weighted 30-day rolling average emission limit
of 0.11 lb/MMBtu for NOX for Units 1-5. For PM, we are
proposing a BART emission limit of 0.012 lb/MMBtu from Units 1-3 on a
6-hour average basis and 0.015 lb/MMBtu averaged over a 6-hour period
for Units 4 and 5, which should be achievable with proper operation of
the existing baghouses. EPA is also proposing that Units 1-5 meet a 10%
opacity limit which will reasonably assure continuous compliance with
the PM emission limits. EPA is taking comment on an alternative PM
emission limit for Units 1-3.
The available control technologies and EPA's evaluation of each of
the five factors supporting our proposed BART emissions limits for
NOX and PM are discussed in more detail below and in EPA's
accompanying Technical Support Document (TSD).
C. Available and Feasible Control Technologies and Five Factor Analysis
for NOX Emissions
APS identified sixteen options as available retrofit technologies
to control NOX. Generally, NOX control techniques
use: (1) Combustion control to reduce the production of NOX
from fuel-bound nitrogen and high temperature combustion; (2) post-
combustion add-on control to reduce the amount of NOX
emitted in flue gas by converting NOX to diatomic nitrogen
(N2); or (3) a combination of combustion and post-combustion
controls. EPA approached the five factor analysis using a top-down
method. A top-down analysis entails ranking the control options in
descending order starting with the most stringent option. The top
control option is evaluated and if eliminated based on one of the five
factors, the next most stringent option is considered, and so on. The
top option for NOX control is a combination of a post-
combustion add-on control, i.e., selective catalytic reduction (SCR),
and combustion controls, i.e., low-NOX burners plus overfire
air (LNB + OFA). SCR without LNB + OFA represents the next most
stringent option, and LNB + OFA without SCR represents a low-mid level
of control. As described in detail below, EPA believes LNB + OFA are
not likely to be effective control technologies at FCPP due to the
inherent limitations of the existing boilers on all units. Therefore,
EPA started our top-down analysis of the five factors with SCR without
combustion controls. More details on the control options are provided
in Section 2 of the TSD.
As described in our ANPRM, APS has claimed that combustion controls
(i.e., low-NOX burners (LNB) on Units 1 and 2 and low
NOX burners plus overfire air (LNB + OFA) on Units 3-5)
would provide NOX reductions sufficient to meet the
presumptive limits for NOX identified in the BART Guidelines
(40 CFR Part 51 Appendix Y). Table 1 shows the presumptive
NOX limits for boilers burning either sub-bituminous or
bituminous coal and the emission limits APS considers achievable for
Units 1-5. APS submitted NOX emission limits it considers
achievable to EPA in January 2008, March 2009, and October 2009. The
coal burned at FCPP has historically been classified as sub-bituminous.
APS, however, in its BART analysis has claimed that the coal is
bituminous.
Table 1--Presumptive NOX Limits4 and NOX Emissions (in lb/MMBtu) From LNB (Units 1 and 2) LNB + OFA (Units 3-5)
Claimed Achievable by APS
----------------------------------------------------------------------------------------------------------------
Emissions after Emissions after
Bituminous coal Sub-Bituminous LNB or LNB+OFA LNB or LNB+OFA
coal (Jan 2008 \5\) (Oct 2009 \6\)
----------------------------------------------------------------------------------------------------------------
Unit 1.................................. N/A N/A 0.48 0.40
Unit 2.................................. N/A N/A 0.48 0.40
Unit 3.................................. 0.39 0.23 0.39 0.32
Unit 4.................................. 0.40 0.45 0.40 0.35
Unit 5.................................. 0.40 0.45 0.40 0.35
----------------------------------------------------------------------------------------------------------------
EPA, however, disagrees with APS's contention that EPA should rely
only on presumptive limits for BART for NOX and with APS's
claim that LNB and LNB + OFA will be effective at achieving
NOX emissions lower than the presumptive BART emissions
limits.
---------------------------------------------------------------------------
\4\ Presumptive limits for Unit 3 based on dry-bottom wall-fired
boiler and Units 4 and 5 on cell burner boilers. Presumptive limits
do not apply to Units 1 and 2 because they are smaller than 200 MW.
\5\ From 2008-01--APS--4--Corners--BART--Analysis--
Conclusions.pdf.
\6\ From APS's Comment Letter to EPA dated October 28, 2009.
---------------------------------------------------------------------------
[[Page 64226]]
EPA's presumptive BART limits were not intended to supplant a case-
by-case BART determination. For NOX, for most types of
boilers, EPA's presumptive BART limits were intended to indicate what
should generally be achievable with combustion modifications such as
modern LNB with OFA for a given type of boiler firing either bituminous
or sub-bituminous coal. In establishing the presumptions, EPA concluded
that these controls were highly cost-effective at large power plants
generally and that installation of such controls would result in
meaningful visibility improvement at any 750 MW power plant. Thus,
these controls are required at a minimum at these facilities unless
there are source-specific circumstances that would justify a different
conclusion. EPA did not consider the question of what more stringent
control technologies might be appropriately determined to be BART,
however, especially in the case where the visibility benefits may be
substantial. A full case-by-case BART analysis is required for each
facility. In this instance, given the fact that FCPP is the largest
source of NOX emissions in the United States and that it is
surrounded by 16 mandatory Class I areas, EPA considers it appropriate
to carefully consider NOX emission limits based on a full
analysis of the five BART factors. In this rulemaking, EPA is
undertaking a complete BART analysis for the FCPP for the first time,
an analysis that is specific to FCPP and that takes into consideration
the five factors set forth in the CAA.
Because EPA is relying on the five-factor analysis and not the
presumptive NOX levels in the BART guidelines, it is not
necessary for EPA to make a determination on the classification of coal
used by APS as bituminous or sub-bituminous. EPA is taking the coal
characteristics into account in establishing the NOX BART
emission limit, but the classification as bituminous or sub-bituminous
is only relevant for choosing presumptive limits, which we are not
doing in this proposal. Although the emissions level claimed by APS for
LNB + OFA retrofit of Units 4 and 5 are below the presumptive limits
for both sub-bituminous coal and bituminous coal, we note that the
presumptive levels of 0.40 and 0.45 lb/MMBtu provide little reduction
of baseline NOX emissions (0.49 lb/MMBtu) from these units.
In our ANPRM, EPA questioned the ability of LNB and LNB + OFA to
result in the magnitude of NOX reductions being claimed as
achievable by APS. APS has submitted two different reports concerning
the potential for NOX reductions at FCPP. The first report
written by Andover Technology Partners \7\ (Andover Report) was
submitted by APS by letter dated August 7, 2009, prior to the
publication of the ANPRM.\8\ The Andover Report outlined the
considerable challenges associated with LNB and OFA retrofits on each
unit, including boiler design and size, and FCPP coal characteristics.
Although four different technology suppliers claimed they could achieve
NOX reductions with burner retrofits, the Andover Report
concluded that LNB retrofits were not likely to be beneficial for the
boilers at FCPP because the risk of adverse operational side effects
outweighed the potentially modest improvement in emissions performance.
---------------------------------------------------------------------------
\7\ ``Assessment of Potential for Further NOX
Reduction by Combustion-Based Control at the Four Corners Steam
Electric Station'', April 5, 2004.
\8\ EPA received the Andover Report only a few days prior to
signature of the ANPRM. Therefore the report was not considered in
the ANPRM or made available in the ANPRM docket. APS claimed the
report Confidential Business Information (CBI) and on July 9, 2010,
EPA's Regional Counsel determined this report was not CBI.
---------------------------------------------------------------------------
The fireboxes for Units 1, 2 and 3 are considered to be too small
to effectively use modern approaches to low NOX combustion,
which require separated OFA. Unit 2 was retrofitted with a 1990-
designed LNB and, according to APS, had considerable operational
problems subsequent to this retrofit. Units 1 and 2 are identical
boilers. Thus due to operational difficulties following the Unit 2
retrofit, APS did not attempt a retrofit on Unit 1, which continues to
emit NOX at a concentration as high as 0.8 lb/MMBtu.
Units 4 and 5 were originally designed and operated with cell
burners. This type of combustion burner inherently creates more
NOX than conventional wall-fired burners. Although the type
of burners in the cell boilers were replaced in the 1980s, the design
of a cell boiler limits the NOX reduction that can be
achieved with modern low NOX combustion techniques. EPA set
different presumptive levels of 0.40 lb/MMBtu or 0.45 lb/MMBtu for the
expected achievable NOX reductions for cell burner boilers
with combustion modifications due to this design limitation. Thus, the
efficacy of LNB + OFA on Units 4 and 5 will also be limited by their
inherent design. Even if retrofit of Units 4 and 5 results in some
improvement in NOX performance (approaching 0.40 lb/MMBtu),
the Andover Report did not recommend burner retrofits because potential
operational problems on the two largest units at FCPP were not worth
the small incremental reduction in NOX emissions.
A subsequent report prepared by APS and submitted to EPA as
Attachment J of its October 28, 2009 comment letter on the ANPRM,
indicated that Units 1 and 2 could achieve 0.40 lb/MMBtu with LNB
retrofit, Unit 3 could achieve 0.32 lb/MMBtu and Units 4 and 5 could
achieve 0.35 lb/MMBtu with a combination of LNB + OFA retrofit. See
Table 1 above. APS cited examples of several boilers with LNB or LNB +
OFA retrofits that achieve emission rates of 0.4 lb/MMBtu or below.
EPA Clean Air Markets Division (CAMD) evaluated the boiler examples
from Attachment J to assess the emissions reductions that have been
achieved with modern combustion modification retrofits. CAMD concluded
that other boilers have achieved NOX emissions of
approximately 0.4 lb/MMBtu, but could not determine if Units 3-5 at
FCPP were indeed comparable to those boilers. APS did not provide
enough information in Attachment J to assess the level of similarity.
Based on information provided in the Andover Report and the EPA CAMD
review of Attachment J provided by APS, EPA determined that combustion
controls are not likely to be effective control technologies at FCPP
due to the inherent limitations of the existing boilers on all units.
Therefore, EPA rejected the top control option, SCR in combination with
LNB + OFA, and focused our five factor analysis on the next most
stringent technology, SCR without LNB + OFA, which can reduce
NOX emissions by 80%.
i. Factor 1: Cost of Compliance
The cost effectiveness of controls is expressed in cost per ton of
pollutant reduced ($/ton). 40 CFR Part 51, App. Y, IV.D.4.c. Cost
effectiveness is calculated by first estimating the total capital and
annual costs of the BART controls. The second step requires calculating
the amounts of the pollutants which will be reduced by the control
technology selected as BART. This second step compares the uncontrolled
baseline emissions (i.e. emissions from current operations) to the
proposed BART emissions limits. Id.
APS submitted cost estimates for all feasible control options in
January 2008 and submitted revised cost estimates for SCR on March 16,
2009 to reflect higher costs of construction services and materials. In
our August 28, 2009 ANPRM, we presented APS's cost estimates for
emissions controls for NOX, which included the revised SCR
costs submitted in March 2009, and cost estimates from the National
Park Service
[[Page 64227]]
(NPS). In the ANPRM, EPA revised the annual operating cost estimates
submitted by APS based on the ratio of annual to capital costs from
other facilities in the western United States. NPS conducted an
independent analysis strictly adhering to the EPA Control Cost Manual
and calculated significantly lower cost effectiveness. In subsequent
comments on the ANPRM, NPS submitted revised cost estimates for each
unit. All of these cost estimates are described in detail in the TSD.
Subsequent to the ANPRM, APS submitted revised cost estimates for
the NOX control technologies. APS provided these revised
cost estimates to EPA via electronic mail on April 22, 2010, in a
report dated February 10, 2010. Costs estimated for Unit 1-3 were dated
May 2008, whereas revised cost estimates were provided for Units 4 and
5 were dated February 2010. All cost estimates in the 2010 submission
were lower than those submitted previously. The report updated cost
estimates for Units 4 and 5 in 2010 dollars and provided cost estimates
for Units 1-3 in 2008 dollars that are lower than the costs APS
submitted in March 2009 upon which the ANPRM relied. Because APS only
recently withdrew a claim of confidentiality for the 2010 cost
estimates, however, this proposal is based on the costs submitted in
March 2009. The TSD also contains a further discussion of these costs.
For this NPR, EPA evaluated the capital and annual cost estimates
APS submitted in March 2009 against the EPA Control Cost Manual.
Although EPA has generally accepted the costs estimates APS submitted,
we have eliminated any line item costs that are not explicitly included
in the EPA Control Cost Manual and we have revised the costs where EPA
determined alternate costs were more appropriate, e.g., cost of
catalysts, or interest rates. Additional detailed information and the
results of our revisions to the cost estimates are included in Table 13
of the TSD. EPA's cost effectiveness estimates and those estimated by
NPS and APS are shown in Table 2.
Table 2--EPA, NPS, and APS Cost Effectiveness for SCR on Units 1-5
----------------------------------------------------------------------------------------------------------------
EPA Cost NPS Cost APS Cost
effectiveness ($/ effectiveness ($/ effectiveness ($/
ton) ton) ton)
----------------------------------------------------------------------------------------------------------------
Unit 1................................................. $2,515 $1,326 $4,887
Unit 2................................................. 3,163 1,882 6,170
Unit 3................................................. 2,678 1,390 5,142
Unit 4................................................. 2,622 1,453 5,197
Unit 5................................................. 2,908 1,598 5,764
----------------------------------------------------------------------------------------------------------------
EPA's cost effectiveness calculations in this NPR are lower than we
presented in the ANPRM. The estimates continue to be lower than those
estimated by APS but higher than those estimated by NPS. The range of
cost effectiveness that EPA has calculated and upon which this proposal
is based, from $2,515-$3,163/ton of NOX removed, is lower
than or within the range of other BART evaluations. Some BART analyses
for other electric generating facilities evaluated SCR with a range of
costs: Pacificorps Jim Bridger Units 2-4: $2,256-$4,274/ton of
NOX removed; Pacificorps Naughton Units 1-3: $2,751-$2,830/
ton of NOX removed; PGE Boardman: $3,096/ton of
NOX removed; M.R. Young Units 1 and 2: $3,950-$4,250/ton of
NOX removed; and Centralia Power Plant Units 1 and 2:
$9,091/ton of NOX removed. San Juan Generating Station in
Farmington, New Mexico, is a nearby coal fired power plant that was
built shortly after FCPP and uses coal with almost identical
characteristics. On June 21, 2010, the New Mexico Environmental
Department proposed requiring SCR as BART for the four units at San
Juan Generating Station based on cost-effectiveness calculations
ranging from $5,946/ton NOX reduced to $7,398/ton
NOX reduced.
EPA considers its revised cost-effectiveness estimates of $2,515-
$3,163/ton of NOX removed to be more accurate and
representative of the actual cost of compliance. However, even if EPA
had decided to accept APS's worst-case cost estimates of $4,887-$6,170/
ton of NOX removed, EPA considers that estimate to be cost
effective for the purpose of proposing an 80% reduction in
NOX, achievable by installing and operating SCR as BART at
FCPP.
ii. Factor 2: Energy and Non-Air Quality Impacts
The Navajo Nation has expressed concerns that requiring additional
controls at FCPP could result in lost Navajo employment and royalties
if FCPP were to shut down or curtail operations. EPA has received no
definitive information indicating that FCPP intends to shut down or
curtail operations, but to assess the possibility that today's proposed
BART limits could have such an effect, EPA conducted an economic
analysis that looked at the impact of requiring SCR on FCPP.
Based on an economic analysis of the increase in electricity
generation costs as a result of SCR compared to the estimated cost to
purchase electricity on the wholesale market, FCPP is expected to
remain competitive relative to the wholesale market, suggesting that
the incremental cost increase for SCR alone should not force FCPP to
shut down. This analysis estimates that the average cost of electricity
generation over the 20 year amortization period as a result of SCR
implementation will increase by 22%, or $0.00740/kWh.
Retail electricity consumers, however, pay more than just the
generation costs of power. Retail rates include the cost to transmit
and distribute electricity as well as generate electricity.
Additionally, for APS customers, for example, the generation cost
increase on FCPP due to SCR would flow into a broader retail rate
impact calculation based on the entire portfolio of APS generation
assets and purchases power contracts, which include coal (of which FCPP
is only a portion of APS' total coal portfolio), natural gas, nuclear,
and some renewables. For these reasons, EPA expects the potential rate
increase to APS rate payers resulting from SCR on FCPP to be
significantly lower than 22%. This topic is discussed in more detail in
the TSD.
In addition to concerns about possible facility shut down, EPA
received comments regarding potential impacts of increased
transportation emissions associated with urea deliveries to FCPP for
SCR and concerns of the affect of SCR on salability of fly ash. EPA
conducted an analysis to evaluate any increase in health risks
resulting from increased diesel truck traffic to and from FCPP and
determined that the increase in cancer and non-cancer health risks
[[Page 64228]]
associated with transportation emissions in the most impacted census
block in San Juan County, New Mexico, are well below background levels
and will not result in a significant health risk.
The Salt River Pima Maricopa Indian Community expressed concern
about the impact of SCR on their Phoenix Cement Company fly ash
business unit at FCPP. Ammonia adsorption (resulting from ammonia
injection from SCR or selective noncatalytic reduction--SNCR) to fly
ash is generally less desirable due to odor but does not impact the
integrity of the use of fly ash in concrete. However, other
NOX control technologies, including LNB, also have
undesirable impacts on fly ash. LNBs increase the amount of unburned
carbon in the fly ash, also known as Loss of Ignition (LOI), which does
affect the integrity of the concrete. Commercial-scale technologies
exist to remove ammonia and LOI from fly ash. Therefore, EPA has
determined that the impact of SCR on the fly ash at FCPP is smaller
than the impact of LNB on the fly ash, and in both cases, the adverse
effects can be mitigated.
EPA concludes that the energy and non-air quality impacts of SCR do
not warrant elimination of SCR as the top control option for
NOX.
iii. Factor 3: Existing Controls at the Facility
There are some existing controls at FCPP for NOX. APS
has installed a variety of LNB on Units 2-5 although these controls are
all about 20 years old and there have been significant advances in the
technology for most EGU boilers. Unit 1 does not have any
NOX controls. The controls that APS is operating at FCPP for
NOX do not result in the magnitude of NOX
emissions reduction that are consistent with BART and do not represent
current control technologies.
iv. Factor 4: Remaining Useful Life of Facility
The remaining useful life of the facility can be relevant if the
facility may shut down before the end of the amortization period used
to annualize the costs of control for a technology. In its analysis,
APS used an amortization period of 20 years, the standard amortization
period recommended by EPA, and indicated that it anticipated that the
remaining useful life of Units 1-5 is at least 20 years. As it appears
that the FCPP facility will continue to operate for at least 20 years,
EPA agrees with the use of an amortization period of 20 years to
estimate costs.
v. Factor 5: Degree of Visibility Improvement
The fifth factor to consider under EPA's BART Guidelines is the
degree of visibility improvement from the BART control options. See 59
FR at 39170. The BART guidelines recommend using the CALPUFF air
quality dispersion model to estimate the visibility improvements of
alternative control technologies at each Class I area, typically those
within a 300 km radius of the source, and to compare these to each
other and to the impact of the baseline (i.e., current) source
configuration. APS included sixteen Class I Areas in its modeling
analysis; fifteen are within 300 km of FCPP and one Class I area, Grand
Canyon National Park, is just beyond 300 km from FCPP. These areas are
listed in Table 22 of the TSD.
The BART guidelines recommend comparing visibility improvements
between control options using the 98th percentile of 24-hour delta
deciviews, which is roughly equivalent to the facility's 8th highest
visibility impact day. The ``delta'' refers to the difference between
total deciview impact from the facility plus natural background, and
deciviews of natural background alone, so ``delta deciviews'' is the
estimate of the facility's impact. Visibility is traditionally
described in terms of visual range in kilometers or miles. However, the
visual range scale does not correspond to how people perceive
visibility because how a given increase in visual range is perceived
depends on the starting visibility against which it is compared. Thus,
an increase in visual range may be perceived to be a big improvement
when starting visibility is poor, but a relatively small improvement
when starting visibility is good.
The ``deciview'' scale is designed to address this problem. It is
linear with respect to perceived visibility changes over its entire
range, and is analogous to the decibel scale for sound. This means that
a given change in deciviews will be perceived as the same amount of
visibility change regardless of the starting visibility. Lower deciview
values represent better visibility and greater visual range, while
increasing deciview values represent increasingly poor visibility. In
the BART guidelines, EPA noted that a 1.0 deciview impact from a source
is sufficient to ``cause'' visibility impairment and that a source with
a 0.5 deciview impact must ``contribute'' to visibility impairment.
Generally, 0.5 deciviews is the amount of change that is just
perceptible to a human observer.
Under the BART guidelines, the improved visibility in deciviews
from installing controls is determined by using the CALPUFF air quality
model. CALPUFF, generally, simulates the transport and dispersion of
FCPP emissions, and the conversion of SO2 emitted from FCPP
to particulate sulfate and NOX to particulate nitrate, at a
rate dependent on meteorological conditions and background ozone
concentration. These concentrations are then converted to delta
deciviews by the CALPOST post-processor. The CALPUFF model and CALPOST
post-processing are explained in more detail in the TSD.
The ``delta deciviews'' estimated by the modeling represents the
facility's impact on visibility at the Class I areas. Each modeled day
and location in the Class I area will have an associated delta
deciviews. For each day, the model finds the maximum visibility impact
of all locations (i.e., receptors) in the Class I area. From among
these daily values, the BART guidelines recommend use of the 98th
percentile, which is roughly equivalent to the 8th highest day for a
given year, for comparing the base case and the effects of various
controls. The 98th percentile is recommended rather than the maximum
value to avoid undue influence from unusual meteorological conditions.
Meteorological conditions are modeled using the CALMET model.
APS conducted modeling for FCPP according to a modeling protocol
submitted to EPA. See BART Visibility Modeling Protocol for the Arizona
Public Service Four Corners Power Plant, ENSR Corporation, January
2008. APS's modeling used the CALMET and CALPUFF versions recommended
by EPA but in blending in meteorological station wind observations, APS
used a lower radius of influence for stations. This change resulted in
smoother wind fields. After initial input from the Federal Land
Managers, EPA requested APS to change certain other CALMET option
settings. These changes resulted in a more refined approach that is
more consistent with approaches used in PSD permit application
modeling. Further details about the CALPUFF and CALMET modeling are in
the TSD, and the relevant CALMET settings are listed in Table 23.
In addition to the different CALPUFF emission rates described
above, EPA's evaluation of anticipated visibility improvement used
revised post-processor settings from those originally used by APS. The
USFS informed EPA that the ammonia background concentrations modeled by
APS in January 2008 were lower than observed
[[Page 64229]]
concentrations.\9\ The USFS recommended a method of back-calculating
the ammonia background based on monitored values of sulfate and
nitrate. EPA's ANPRM provided results based on using the USFS's back-
calculation methodology.
---------------------------------------------------------------------------
\9\ Letter from Rick Cables (Forest Service R2 Regional
Forester) and Corbin Newman (Forest Service R3 Regional Forester) to
Deborah Jordan (EPA Region 9 Air Division Director) dated March 17,
2009.
---------------------------------------------------------------------------
The visibility modeling supporting today's proposal, however, uses
a constant ammonia background of 1 ppb, which is the default value
recommended for western areas. IWAQM Phase 2 document.\10\ The TSD
contains supplemental modeling using back-calculated ammonia
concentrations, a thorough discussion of the back-calculation
methodology and the sensitivity results based on selecting different
concentrations of background ammonia.
---------------------------------------------------------------------------
\10\ Interagency Workgroup On Air Quality Modeling (IWAQM) Phase
2 Summary Report And Recommendations For Modeling Long Range
Transport Impacts (EPA-454/R-98-019), EPA OAQPS, December 1998,
http://www.epa.gov/scram001/7thconf/calpuff/phase2.pdf.
---------------------------------------------------------------------------
The background values of ammonia are important because it is a
precursor to particulate ammonium sulfate and ammonium nitrate, both of
which degrade visibility. Ammonia is present in the air from both
natural and anthropogenic sources. The latter may include livestock
operations, fertilizer application associated with farming, and ammonia
slip from the use of ammonia in SCR and SNCR technologies to control
NOX emissions. Sensitivity of the model results to other
ammonia assumptions are discussed in the TSD, and do not change the
ranking of control options for evaluating visibility improvement, or
the overall conclusions of the visibility analysis.
In our modeling input for ammonia, EPA assumed that the remaining
ammonia in the flue gas following SCR reacts to form ammonium sulfate
or ammonium bisulfate before exiting the stack. This particulate
ammonium is represented in the modeling as sulfate (SO4)
emissions. Thus, EPA addressed ammonia solely as a background
concentration.
In the supplemental sensitivity analyses using different ammonia
values described in the TSD, ammonia concentrations for Mesa Verde
National Park were not based on the back-calculation method, but
instead were derived from measured ammonia concentrations in the Four
Corners area, as described in Sather et al., (2008).\11\ Monitored data
were available within Mesa Verde NP, but because particulate formation
happens within a pollutant plume as it travels, rather than
instantaneously at the Class I area, EPA also examined data at
locations outside Mesa Verde NP itself. Monitored 3-week average
ammonia at the Substation site, some 30 miles south of Mesa Verde, were
as high as 3.5 ppb, though generally levels were less than 1.5 ppb.
Maximum values in Mesa Verde were 0.6 ppb, whereas other sites' maxima
ranged from 1 to 3 ppb, but generally values were less than 2 ppb. EPA
used values estimated from Figure 5 of Sather et al., (2008), in the
mid-range of the various stations plotted. The results ranged from 1.0
ppb in winter to 1.5 ppb in summer. See TSD, Table 33.
---------------------------------------------------------------------------
\11\ Mark E. Sather et al., 2008. ``Baseline ambient gaseous
ammonia concentrations in the Four Corners area and eastern
Oklahoma, USA''. Journal of Environmental Monitoring, 2008, 10,
1319-1325, DOI: 10.1039/b807984f.
---------------------------------------------------------------------------
The BART determination guidelines recommend that visibility impacts
should be estimated in deciviews relative to natural background
conditions. CALPOST, a CALPUFF post-processor, uses background
concentrations of various pollutants to calculate the natural
background visibility impact. EPA used background concentrations from
Table 2-1 of ``Guidance for Estimating Natural Visibility Conditions
Under the Regional Haze Rule.'' \12\ Although the concentration for
each pollutant is a single value for the year, this method allows for
monthly variation in its visibility impact, which changes with relative
humidity. The resulting deciviews differ by roughly 1% from those
resulting from the method originally used by APS.
---------------------------------------------------------------------------
\12\ U.S. Environmental Protection Agency, EPA-454/B-03-005,
September 2003, on web page http://www.epa.gov/ttn/oarpg/t1pgm.html,
with direct link http://www.epa.gov/ttn/oarpg/t1/memoranda/rh_envcurhr_gd.pdf.
---------------------------------------------------------------------------
To assess results from the CALPUFF model and post-processing steps,
in addition to considering deciview changes directly, EPA used a least-
squares regression analysis of all visibility modeling output from the
2001-2003 modeling period to determine the percent improvement in
FCPP's visibility impact (in delta deciviews) resulting from the
application of control technologies compared to the FCPP's baseline
impacts.
As outlined in the 1999 Regional Haze rule (64 FR 35725, July 1,
1999), a one deciview change in visibility is a small but noticeable
change in visibility under most circumstances when viewing scenes in a
Class I area. Table 3 presents the visibility impacts of the 98th
percentile of daily maxima for each Class I area for each year,
averaged over 2001-2003.\13\ The modeled visibility improvement at all
Class I areas exceeds 0.5 deciviews and at most Class I areas exceeds 1
deciview.
---------------------------------------------------------------------------
\13\ EPA did not average the 98th percentiles from each year as
did APS, rather EPA used the 98th percentile from all three years
taken together. This does not significantly affect the overall
results.
Table 3--EPA Modeling Results--8th High Delta dv Improvement and Percent Change in Delta Deciview (dv) Impact From NOX Controls Compared to Baseline
Impacts From 2001-2003 Using 1 ppb Ammonia Background Scenario
--------------------------------------------------------------------------------------------------------------------------------------------------------
Distance to Baseline Improvement from LNB/LNB + OFA Improvement from SCR
FCPP impact ---------------------------------------------------------------
Class I area --------------------------------
Kilometers Delta dv % Delta dv %
(km) Delta dv
--------------------------------------------------------------------------------------------------------------------------------------------------------
Arches National Park.................................... 245 4.11 0.87 18 2.40 55
Bandelier Wilderness Area............................... 216 2.90 0.54 21 1.62 57
Black Canyon of the Gunnison WA......................... 217 2.36 0.46 23 1.42 60
Canyonlands NP.......................................... 214 5.24 0.79 16 2.81 51
Capitol Reef NP......................................... 283 3.23 0.77 18 1.87 52
Grand Canyon NP......................................... 345 1.63 0.34 20 0.88 55
Great Sand Dunes NM..................................... 279 1.16 0.31 25 0.67 62
La Garita WA............................................ 202 1.72 0.44 25 1.05 62
Maroon Bells Snowmass WA................................ 294 1.04 0.27 26 0.64 63
[[Page 64230]]
Mesa Verde NP........................................... 62 5.95 0.62 13 2.43 45
Pecos WA................................................ 258 2.16 0.52 23 1.15 58
Petrified Forest NP..................................... 224 1.40 0.27 21 0.65 56
San Pedro Parks WA...................................... 160 3.88 0.68 19 2.02 53
Weminuche WA............................................ 137 1.87 0.49 25 1.19 62
West Elk WA............................................. 245 2.76 0.65 23 1.70 60
Wheeler Peak WA......................................... 265 1.53 0.37 24 0.84 59
-----------------------------------------------------------------------------------------------
Total Delta dv or Average % Change in Delta dv...... .............. 42.94 8.39 21 23.34 57
--------------------------------------------------------------------------------------------------------------------------------------------------------
Because installation and operation of SCR at FCPP to reduce
NOX emissions by 80% will provide perceptible and
significant visibility improvements at all of the surrounding Class I
areas, and because LNB will result in much less visibility improvement
than SCR, EPA is proposing to require FCPP to reduce NOX by
80% by meeting a plant-wide emissions limit of 0.11 lb/MMBtu, which is
achievable with SCR. Our analysis also shows that the visibility
improvement from the emissions reductions achieved with LNB are
significantly lower.
D. Available and Feasible Control Technologies and Five Factor Analysis
for PM Emissions
For PM, APS identified seven options as available retrofit
technologies that would rely on post-combustion capture of the
emissions. APS determined three options were technically feasible for
PM control on Units 1-3: Wet electrostatic precipitators (ESPs), dry
ESPs, and pulse jet fabric filters (PJFF or baghouses). These three
control options were determined to all have similar levels of PM
control of 99.9%. One control option, called the GE-MAX-9 hybrid, which
is an ESP using a fabric filter collection bag, is estimated to have a
PM control efficiency of 99.999% and has been used in a demonstration
project, but has not been demonstrated on larger units. Therefore, EPA
considered the other top three options, wet and dry ESP and baghouses,
for PM control at FCPP.
APS has been operating venturi scrubbers on Units 1-3 at FCPP since
the 1970s resulting in PM reductions as well as SO2
reductions. PM is controlled on Units 4 and 5 with baghouses. Venturi
scrubbers have been used by large coal fired electric generating units
(EGUs), but since promulgation of the New Source Performance Standards,
have largely been replaced by more advanced technology that can achieve
better PM reductions and provide better compliance assurance. Units 1-3
at FCPP are the last EGUs in Region 9 to continue to operate venturi
scrubbers. The other EGUs in Region 9 have generally been retrofit with
baghouses.
In this NPR, EPA is proposing to require APS to upgrade its PM
controls as described below to meet an emission limit of 0.012 lb/MMBtu
and 10% opacity on Units 1-3, which is achievable either through
installing baghouses or ESPs. Because of the high incremental cost of
both options, however, EPA is also asking for comment on whether APS
can satisfy BART by operating the existing venturi scrubbers to meet an
emissions limit of 0.03 lb/MMBtu with a 20% opacity limit to
demonstrate continuous compliance. EPA is proposing to require APS to
operate the existing baghouse for Units 4 and 5 to meet an emissions
limit of 0.015 lb/MMBtu and 10% opacity.
i. Factor 1: Cost of Compliance
EPA is proposing to require APS to install ESPs (wet or dry) or
PJFFs for Units 1-3 to comply with an emissions limit of 0.012 lb/MMBtu
and a 10% opacity limit. For Units 4 and 5, APS would not need to
install any controls in addition to the baghouses currently in place
but would be required to operate the baghouses to meet an emission
limit of 0.015 lb/MMBtu and a 10% opacity limit.
The wet-membrane ESP is the lowest cost approach to meeting the
proposed PM BART limit of 0.012 lb/MMBtu for Units 1-3, but a wet
membrane ESP would result in a very high cost effectiveness value for
incremental cost because the existing venturi scrubbers are removing
much of the PM. In other words, any control device, such as an ESP,
placed downstream of the venturi scrubbers will result in a high
incremental cost because the denominator (tons removed) of the cost
effectiveness calculation will be relatively small.
Alternatively, APS could install baghouses on Units 1-3 at FCPP
upstream of the venturi scrubbers. The baghouses would be the most
likely choice for APS for PM control if APS also wants to achieve
significant mercury (``Hg'') reduction from these units. Installing
baghouses would make those controls the primary PM control device (i.e.
the downstream venturi scrubbers would primarily control SO2
emissions) and the cost effectiveness for Units 1-3 would average less
than $110 per ton of PM removed. These costs are discussed further in
Section 3 of the TSD.
Baghouses have already been installed on the four other coal fired
EGUs in Region 9 that had historically used venturi scrubbers for PM
control, including the only other venturi scrubber owned and operated
by APS at its Cholla Unit 1. NV Energy Reid Gardner offered to install
baghouses at Units 1, 2, and 3 as extra injunctive relief in a
settlement agreement. Those baghouses are installed and operating
(despite the high incremental dollars per ton of PM removed) to allow
the units to achieve continuous compliance with PM and opacity limits
and to prepare for the upcoming utility MACT regulation of Hg.
EPA considers installation of either ESPs (wet or dry) or baghouses
as reasonable-cost technology capable of achieving the proposed BART
emission limit of 0.012 lb/MMBu for Units 1-3. However, because of the
high incremental costs associated with ESPs or baghouses, EPA is also
asking for
[[Page 64231]]
comment on whether APS can satisfy BART by continuing to operate the
venturi scrubbers on Units 1-3, demonstrating compliance with an
emissions limit of 0.03 lb/MMBtu with a continuous opacity limit of
20%. EPA's basis for establishing a PM emissions limit of 0.03 lb/MMBtu
is consistency with NSPS Subpart Da, which has been the applicable
emissions limit for any boiler placed into service after 1978. We
believe that an emissions limit that has been in place for over 35
years should be achievable with the venturi scrubbers. We provide
further discussion of this issue in Subsection D.3 below and the TSD.
ii. Factor 2: Energy and Non-Air Quality Impacts
EPA is not aware of any energy and non-air quality impacts
associated with any of the technologies discussed above that would
eliminate them from consideration as BART.
iii. Factor 3: Existing Controls at the Facility
Units 1-3 are controlled by venturi scrubbers, which also are used
for SO2 control. These scrubbers operate at pressure drops
less than 10 inches of water. Venturi scrubbers have not been installed
for PM pollution control on any coal fired EGU in Region 9 since the
early 1970s. Venturi scrubbers have not been in use since that time
principally due to concerns over the ability of venturi scrubbers to
continuously meet the 0.10 lb/MMBtu standard established by a New
Source Performance Standard in 1971. See 40 CFR Part 60 Subpart D.
Fossil fuel fired boiler standards for coal fired units were revised
for units built after 1978 and the PM limit was lowered to 0.03 lb/
MMBtu. See 40 CFR Part 60 Subpart Da. Most current coal fired boilers
now use baghouses which are capable of meeting PM limits of about 0.01
to 0.012 lb/MMBtu.
As mentioned earlier in the cost discussion, baghouses have already
been installed on the four other coal fired EGUs in Region 9 that had
historically used venturi scrubbers for PM control, including APS's
Cholla Unit 1. These baghouses were installed, despite the very high
incremental dollars per ton of PM removed, to allow the companies to
continue to operate the units in continuous compliance with their PM
and opacity limits.
EPA notes that Units 1-3 at FCPP were operated with a re-heat of
the scrubber exhaust. This allows the use of Continuous Opacity
Monitors (COMs) in their stacks and provides an ongoing measurement of
the opacity compliance. EPA understands that these three units
originally installed and operated a re-heat system, but FCPP
discontinued its use. EPA Region 9 is not aware of when APS
discontinued using the re-heat system. The three venturi-equipped
units, Units 1-3, do not have COMs or opacity limits, which are
required on all other EGUs in Region 9 and likely all across the U.S.
because SIPs, such as Arizona's, generally include a 20% opacity
standard. Opacity standards are a regulatory tool that allows agencies
and the public to ensure continuing compliance for PM.
Over the past several years the PM source testing for Units 1 and 2
have consistently complied with the PM limit of 0.03 lb/MMBtu by
operating the venturi scrubbers. Unit 3 exceeded the limit in 2007 but
after subsequent source tests averages an emission rate of below 0.03
lb/MMBtu.
EPA is requesting comment on allowing APS to continue to operate
the venturi scrubbers on Units 1-3 provided it can demonstrate
compliance with an emissions limit of 0.03 lb/MMBtu (as required by the
NSPS Subpart Da for all post 1978 units) and a continuous opacity limit
of 20%.
iv. Factor 4: Remaining Useful Life of Facility
As with NOX, EPA is assuming that the remaining useful
life of the facility is 20 years.
v. Factor 5: Degree of Visibility Improvement
The modeled visibility improvements resulting from additional PM
control are relatively small. See Table 4.
Table 4--EPA Modeling Results--8th High Delta dv Improvement and Percent Change in Delta Deciview (dv) Impact
From PM Control Compared to Baseline Impacts From 2001-2003 Using 1 ppb Ammonia Background Scenario
----------------------------------------------------------------------------------------------------------------
Distance to FCPP Baseline impact Improvement from PM control
Class I area ------------------------------------------------------------------------
Kilometers (km) Delta dv Delta dv %
----------------------------------------------------------------------------------------------------------------
Arches National Park................... 245 4.11 0.01 0
Bandelier Wilderness Area.............. 216 2.90 0.01 0
Black Canyon of the Gunnison WA........ 217 2.36 0 0
Canyonlands NP......................... 214 5.24 0.02 0
Capitol Reef NP........................ 283 3.23 0.01 0
Grand Canyon NP........................ 345 1.63 0.01 0
Great Sand Dunes NM.................... 279 1.16 0 0
La Garita WA........................... 202 1.72 0 0
Maroon Bells Snowmass WA............... 294 1.04 0 0
Mesa Verde NP.......................... 62 5.95 0.02 1
Pecos WA............................... 258 2.16 0.01 0
Petrified Forest NP.................... 224 1.40 0.01 0
San Pedro Parks WA..................... 160 3.88 0.02 1
Weminuche WA........................... 137 1.87 0 0
West Elk WA............................ 245 2.76 0 0
Wheeler Peak WA........................ 265 1.53 0.01 0
------------------------------------------------------------------------
Total Delta dv or Average % Change in ................ 42.94 0.13 0
Delta dv..............................
----------------------------------------------------------------------------------------------------------------
However, this factor may be somewhat misleading because the model
does not include consideration of the visibility impairing plume that
is almost always present after the steam plume from Units 1-3
evaporates. The
[[Page 64232]]
term EPA uses for this plume is a ``secondary visible plume''. This
secondary visible plume often stretches for over 20 miles from FCPP and
is most apparent in the early mornings when the typical inversions cap
the dispersion of the secondary visible plume. EPA does not have any
information as to whether this secondary visible plume can be seen from
Mesa Verde National Park, the closest Class 1 area to FCPP. EPA Region
9 staff has observed this secondary visible plume in New Mexico out as
far as Aztec and Bloomfield en route to Farmington from Albuquerque.
Therefore, EPA is specifically seeking information on this secondary
visible plume, its frequency and persistence, and whether or not it
affects or can be observed from any Class 1 area.
In the TSD, EPA discusses this secondary visible plume and whether
it is related to the poor control of fine particulates by the venturi
scrubbers. EPA is also seeking information as to whether this plume has
been observed from Units 4 and 5. Although the modeled visibility
improvements from requiring additional PM controls are small, EPA
considers eliminating the secondary visible plume from Units 1-3 to be
important for visibility in the area. EPA is proposing to require APS
to install either ESPs (wet or dry) or baghouses to meet an emissions
limit of 0.012 lb/MMBtu with a 10% opacity limit. EPA is also taking
comment on whether BART can be satisfied by allowing APS to continue to
operate its existing venturi scrubbers on Units 1-3 to demonstrate
compliance with an emissions limit of 0.03 lb/MMBtu with a 20% opacity
limit.
III. EPA Proposed Action on Material Handling Limits
EPA is also proposing dust control requirements for FCPP. These
requirements were included in the FIP that EPA finalized in 2007. APS
appealed this portion of the 2007 FIP and EPA agreed to a voluntary
remand of the dust control requirements to provide further
justification in the record.
FCPP receives approximately 10 million tons of coal per year for
combusting in the Units 1-5. This material moves by conveyor belt
across the property line through numerous transfer points before being
loaded to the storage silos that feed the individual Units. Each of
these transfer points along with the conveyor belts has the potential
for PM emissions. The PM can be minimized by collecting devices or dust
suppression techniques such as covered conveyors or spraying devices at
the transfer points.
After combustion, FCPP has a very large amount of ash that needs to
be handled properly to prevent PM emissions to the air. The coal APS
combusts at FCPP has as much as 25% ash. This means that there are over
a million tons of ash that must be properly transported within the
plant and then disposed. Some of this ash is stored in ash silos and is
sold to companies that use it as an additive for making concrete. Much
of the ash is currently disposed at a relatively new onsite ash
landfill. All of this ash, which has the potential to become airborne
PM, must be properly handled to prevent PM10 NAAQS issues.
FCPP's property line abuts the coal mine property and the entire
coal handling and fly ash storage is within close proximity to Morgan
Lake which is a recreational lake just beyond the FCPP's property line.
EPA has received numerous complaints from Navajo Tribal members
concerning excess dust generated from the new landfill. For these
reasons, EPA considers it necessary or appropriate for dust/PM
suppression measures to be enforceable to protect the ambient air
quality.
EPA is proposing to require APS to implement a dust control plan
and a 20% opacity standard for all material handling operations. The
dust plan must provide measures to ensure that the coal handling, ash
handling and disposal and general dust generating sources do not exceed
20% opacity. Dust control measures at coal fired power plants are
important for maintaining the PM10 NAAQS in the areas
adjacent to the power plant properties. Most coal fired power plants
that are grandfathered from the NSPS Subpart Y (40 CFR part 60) and
from Prevention of Significant Deterioration (PSD) case by case BACT
determinations are covered by general SIP rules regulating emissions
and have associated opacity standards to assure proper operation of
dust control or suppression measures during the times when stack
testing is not conducted. Grandfathered facilities usually were subject
to process weight PM limits under SIPs. These limits used an
exponential equation approach to setting the allowable lb/hr PM based
on the amount of material processed per hour. The limits typically
become more stringent as a ratio of the allowable emissions to the
throughput as the amount of material throughput increases. The SIPs
also apply a general opacity limit to these PM emitting units.
Because FCPP is located on the Navajo Reservation where generally
applicable limits that often are included in SIPs do not exist, and
because dust control measures at coal fired power plants are important
for maintaining the PM10 NAAQS in the areas adjacent to the
power plant properties, EPA finds that it is necessary or appropriate
to impose measures to limit the amount of PM emissions from these
material handling emission sources. EPA recently imposed similar dust
control requirements at the Navajo Generating Station which is also on
the Navajo Nation Reservation.
IV. Administrative Requirements
A. Executive Order 12866: Regulatory Planning and Review
This proposed action is not a ``significant regulatory action''
under the terms of Executive Order (EO) 12866 (58 FR 51735, October 4,
1993) because it is a proposed rule that applies to only one facility
and is not a rule of general applicability. This proposed rule,
therefore, is not subject to review under EO 12866. This action
proposes a source-specific FIP for the Four Corners Power Plant on the
Navajo Nation.
B. Paperwork Reduction Act
This proposed action does not impose an information collection
burden under the provisions of the Paperwork Reduction Act, 44 U.S.C.
3501 et seq. Under the Paperwork Reduction Act, a ``collection of
information'' is defined as a requirement for ``answers to * * *
identical reporting or recordkeeping requirements imposed on ten or
more persons * * *.'' 44 U.S.C. 3502(3)(A). Because the proposed FIP
applies to a single facility, Four Corners Power Plant, the Paperwork
Reduction Act does not apply. See 5 CFR 1320(c).
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; develop, acquire, install, and utilize
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 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
[[Page 64233]]
numbers for EPA's regulations in 40 CFR are listed in 40 CFR Part 9.
C. Regulatory Flexibility Act
The Regulatory Flexibility Act (RFA) generally requires an agency
to prepare a regulatory flexibility analysis of any rule subject to
notice and comment rulemaking requirements under the Administrative
Procedure Act or any other statute unless the agency certifies that the
rule will not have a significant economic impact on a substantial
number of small entities. Small entities include small businesses,
small organizations, and small governmental jurisdictions.
For purposes of assessing the impacts of today's proposed rule on
small entities, small entity is defined as: (1) A small business as
defined by the Small Business Administration's (SBA) regulations at 13
CFR 121.201; (2) a small governmental jurisdiction that is a government
of a city, county, town, school district or special district with a
population of less than 50,000; and (3) a small organization that is
any not-for-profit enterprise which is independently owned and operated
and is not dominant in its field.
After considering the economic impacts of this proposed action on
small entities, I certify that this proposed action will not have a
significant economic impact on a substantial number of small entities.
The FIP for Four Corners Power Plant being proposed today does not
impose any new requirements on small entities. See Mid-Tex Electric
Cooperative, Inc. v. FERC, 773 F.2d 327 (DC Cir. 1985).
D. Unfunded Mandates Reform Act (UMRA)
This proposed rule, if finalized, will impose an enforceable duty
on the private sector owners of FCPP. However, this rule does not
contain a Federal mandate that may result in expenditures of $100
million (in 1996 dollars) or more for State, local, and tribal
governments, in the aggregate, or the private sector in any one year.
EPA's estimate for the total annual cost to install and operate SCR on
all five units at FCPP and the cost to install and operate new PM
controls on Units 1-3 does not exceed $100 million (in 1996 dollars) in
any one year. Thus, this rule is not subject to the requirements of
sections 202 or 205 of UMRA. This proposed action is also not subject
to the requirements of section 203 of UMRA because it contains no
regulatory requirements that might significantly or uniquely affect
small governments. This rule will not impose direct compliance costs on
the Navajo Nation, and will not preempt Navajo law. This proposed
action will, if finalized, reduce the emissions of two pollutants from
a single source, the Four Corners Power Plant.
E. Executive Order 13132: Federalism
Under section 6(b) of Executive Order 13132, EPA may not issue an
action that has federalism implications, that imposes substantial
direct compliance costs on State or local governments, and that is not
required by statute, unless the Federal government provides the funds
necessary to pay the direct compliance costs incurred by State and
local governments, or EPA consults with State and local officials early
in the process of developing the proposed action. In addition, under
section 6(c) of Executive Order 13132, EPA may not issue an action that
has federalism implications and that preempts State law, unless the
Agency consults with State and local officials early in the process of
developing the proposed action.
EPA has concluded that this proposed action, if finalized, may have
federalism implications because it makes calls for emissions reductions
of two pollutants from a specific source on the Navajo Nation. However,
the proposed rule, if finalized, will not impose substantial direct
compliance costs on the Tribal government, and will not preempt Tribal
law. Thus, the requirements of sections 6(b) and 6(c) of the Executive
Order do not apply to this action.
Consistent with EPA policy, EPA nonetheless consulted with
representatives of Tribal governments \14\ early in the process of
developing the proposed action to permit them to have meaningful and
timely input into its development.
---------------------------------------------------------------------------
\14\ ``Representatives of State and local governments'' include
non-elected officials of State and local governments and any
representative national organizations not listed in footnote 3.
---------------------------------------------------------------------------
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, Nov. 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.'' Under Executive Order 13175, to the
extent practicable and permitted by law, EPA may not issue a regulation
that has tribal implications, that imposes substantial direct
compliance costs on Indian tribal governments, and that is not required
by statute, unless the Federal government provides the funds necessary
to pay direct compliance costs incurred by tribal governments, or EPA
consults with tribal officials early in the process of developing the
proposed regulation and develops a tribal summary impact statement. In
addition, to the extent practicable and permitted by law, EPA may not
issue a regulation that has tribal implications and pre-empts tribal
law unless EPA consults with tribal officials early in the process of
developing the proposed regulation and prepares a tribal summary impact
statement.
EPA has concluded that this proposed rule, if finalized, may have
tribal implications because it will require emissions reductions of two
pollutants by a major stationary source located and operating on the
Navajo reservation. However, this proposed rule, if finalized, will
neither impose substantial direct compliance costs on tribal
governments nor pre-empt Tribal law because the proposed FIP imposes
obligations only on the owners or operator of the Four Corners Power
Plant.
EPA has consulted with officials of the Navajo Nation in the
process of developing this proposed FIP. EPA had an in-person meeting
with Tribal representatives prior to the proposal and will continue to
consult with Tribal officials during the public comment period on the
proposed FIP. In addition, EPA provided Navajo Nation and other tribal
governments additional time to submit formal comments on our Advanced
Notice of Proposed Rulemaking. Several tribes, including the Navajo,
submitted comments which EPA considered in developing this NPR.
Therefore, EPA has allowed the Navajo Nation to provide meaningful and
timely input into the development of this proposed rule and will
continue to consult with the Navajo Nation and other affected Tribes
prior to finalizing our BART determination.
G. Executive Order 13045: Protection of Children From Environmental
Health Risks and Safety Risks
Executive Order 13045: Protection of Children from Environmental
Health Risks and Safety Risks (62 FR 19885, April 23, 1997), applies to
any rule that: (1) is determined to be economically significant as
defined under Executive Order 12866, and (2) concerns an environmental
health or safety risk that EPA has reason to believe may have a
disproportionate effect on children. If the regulatory action meets
both criteria, the Agency must evaluate the environmental health or
safety effects of the planned rule on children, and
[[Page 64234]]
explain why the planned regulation is preferable to other potentially
effective and reasonably feasible alternatives considered by the
Agency.
This proposed rule is not subject to Executive Order 13045 because
it requires emissions reductions of two pollutants from a single
stationary source. Because this proposed action only applies to a
single source and is not a proposed rule of general applicability, it
is not economically significant as defined under Executive Order 12866,
and does not have a disproportionate effect on children. However, to
the extent that the rule will reduce emissions of PM and
NOX, which contributes to ozone formation, the rule will
have a beneficial effect on children's health by reducing air pollution
that causes or exacerbates childhood asthma and other respiratory
issues.
H. Executive Order 13211: Actions Concerning Regulations That
Significantly Affect Energy Supply, Distribution, or Use
This action is not subject to Executive Order 13211 (66 FR 28355
(May 22, 2001)), because it is not a significant regulatory action
under Executive Order 12866.
I. National Technology Transfer and Advancement Act
Section 12(d) of the National Technology Transfer and Advancement
Act of 1995 (NTTAA), Public Law 104-113, 12 (10) (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 the VCS bodies.
The NTTAA directs EPA to provide Congress, through annual reports to
OMB, with explanations when the Agency decides not to use available and
applicable VCS.
Consistent with the NTTAA, the Agency conducted a search to
identify potentially applicable VCS. For the measurements listed below,
there are a number of VCS that appear to have possible use in lieu of
the EPA test methods and performance specifications (40 CFR Part 60,
Appendices A and B) noted next to the measurement requirements. It
would not be practical to specify these standards in the current
proposed rulemaking due to a lack of sufficient data on equivalency and
validation and because some are still under development. However, EPA's
Office of Air Quality Planning and Standards is in the process of
reviewing all available VCS for incorporation by reference into the
test methods and performance specifications of 40 CFR Part 60,
Appendices A and B. Any VCS so incorporated in a specified test method
or performance specification would then be available for use in
determining the emissions from this facility. This will be an ongoing
process designed to incorporate suitable VCS as they become available.
EPA is requesting comment on other appropriate VCS for measuring
opacity or emissions of PM and NOX.
Particulate Matter Emissions--EPA Methods 1 though 5.
Opacity--EPA Method 9 and Performance Specification Test 1 for
Opacity Monitoring.
NOX Emissions--Continuous Emissions Monitors.
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 this proposed rule, if finalized, will not
have disproportionately high and adverse human health or environmental
effects on minority or low-income populations because it increases the
level of environmental protection for all affected populations without
having any disproportionately high and adverse human health or
environmental effects on any population, including any minority or low-
income population. This proposed rule requires emissions reductions of
two pollutants from a single stationary source, Four Corners Power
Plant.
List of Subjects in 40 CFR Part 49
Environmental protection, Administrative practice and procedure,
Air pollution control, Indians, Intergovernmental relations, Reporting
and recordkeeping requirements.
Dated: October 6, 2010.
Jared Blumenfeld,
Regional Administrator, Region IX.
Title 40, chapter I of the Code of Federal Regulations is proposed
to be amended as follows:
PART 49--[AMENDED]
1. The authority citation for part 49 continues to read as follows:
Authority: 42 U.S.C. 7401, et seq.
2. Section 49.23 is amended by adding paragraphs (i) and (j) to
read as follows:
Sec. 49.23 Federal Implementation Plan Provisions for Four Corners
Power Plant, Navajo Nation.
* * * * *
(i) Regional Haze Best Available Retrofit Technology limits for
this plant are in addition to the requirements in paragraphs (a)
through (h) of this section. All definitions and testing and monitoring
methods of this section apply to the limits in paragraph (i) of this
section except as indicated in paragraphs (i)(1) through (4) of this
section. Within 180 days of the effective date of this paragraph (i),
the owner or operator shall submit a plan to the Regional Administrator
that identifies the control equipment and schedule for complying with
this paragraph (i). The owner or operator shall amend and submit this
amended plan to the Regional Administrator as changes occur. The
interim limits for each unit shall be effective 180 days after re-start
of the unit after installation of SCR controls for that unit and until
the plant-wide limit goes into effect. The plant-wide NOX
limit shall be effective no later than 5 years after the effective date
of this rule. APS may elect to meet the plant-wide limit early to
remove the individual unit limits. Particulate limits for Units 1, 2,
and 3 shall be effective 180 days after re-start of the units after
installation of the PM controls but no later than 5 years after the
effective date of this paragraph (i). Particulate limits for Units 4
and 5 shall be effective 180 days after re-start of the units after
installation of the SCR controls.
(1) Particulate Matter for units 1, 2, and 3 shall be limited to
0.012 lb/MMBtu for each unit as measured by the average of 3 test runs
with each run collecting a minimum of 60 dscf of sample gas and with a
duration of at least 120 minutes. Sampling shall be performed according
to 40 CFR Part 60 Appendices A-1 through A-3, Methods 1 through 4 and
Method 5 or Method 5e. The averaging time for any other demonstration
of the Particulate Matter compliance or exceedence shall be
[[Page 64235]]
based on a 6 hour average. Particulate testing shall be performed
annually as required by paragraph (e)(3) of this section. This test
with 2 hour test runs may be substituted and used to demonstrate
compliance with the particulate limits in paragraph (d)(2) of this
section.
(2) Particulate Matter from units 4 and 5 shall be limited to 0.015
lb/MMbtu for each unit as measured by the average of 3 test runs with
each run collecting a minimum of 60 dscf of sample gas and with a
duration of at least 120 minutes. Sampling shall be performed according
to 40 CFR Part 60 Appendices A-1 through A-3, Methods 1 through 4 and
Method 5 or Method 5e. The averaging time for any other demonstration
of the particulate matter compliance or exceedence shall be based on a
6 hour average.
(3) No owner or operator shall discharge or cause the discharge of
emissions from the stacks of Units 1, 2, 3, 4 or 5 into the atmosphere
exhibiting greater than 10% opacity, excluding uncombined water
droplets, averaged over any six (6) minute period.
(4) Plantwide nitrogen oxide emission limits.
(i) The plantwide nitrogen oxide limit, expressed as nitrogen
dioxide, shall be 0.11 lb/MMbtu as averaged over a rolling 30 calendar
day period. NO2 emissions for each calendar day shall be
determined by summing the hourly emissions measured in pounds of
NO2 for all operating units. Heat input for each calendar
day shall be determined by adding together all hourly heat inputs, in
millions of BTU, for all operating units. Each day the thirty day
rolling average shall be determined by adding together that day and the
preceding 29 days pounds of NO2 and dividing that total
pounds of NO2 by the sum of the heat input during the same
30 day period. The results shall be the 30 day rolling pound per
million BTU emissions of NOX.
(ii) The interim NOX limit for each individual boiler
with SCR control shall be as follows:
(A) Unit 1 shall meet a rolling 30 calendar day NOX
limit of 0.21 lb/MMBtu,
(B) Unit 2 shall meet a rolling 30 calendar day limit of 0.17 lb/
MMBtu,
(C) Unit 3 shall meet a rolling 30 calendar day limit of 0.16 lb/
MMBtu,
(D) Units 4 and 5 shall meet a rolling 30 calendar day limit of
0.11 lb/MMBtu, each.
(iii) Testing and monitoring shall use the 40 CFR part 75 monitors
and meet the 40 CFR part 75 quality assurance requirements. In addition
to these 40 CFR part 75 requirements, relative accuracy test audits
shall be performed for both the NO2 pounds per hour
measurement and the heat input measurement. These shall have relative
accuracies of less than 20%. This testing shall be evaluated each time
the 40 CFR part 75 monitors undergo relative accuracy testing.
(iv) If a valid NOX pounds per hour or heat input is not
available for any hour for a unit, that heat input and NOX
pounds per hour shall not be used in the calculation of the 30 day
plant wide rolling average.
(v) Upon the effective date of the plantwide NOX
average, the owner or operator shall have installed CEMS and COMS
software that complies with the requirements of this section.
(j) Dust. Each owner or operator shall operate and maintain the
existing dust suppression methods for controlling dust from the coal
handling and ash handling and storage facilities. Within ninety (90)
days after promulgation of this paragraph (j), the owner or operator
shall develop a dust control plan and submit the plan to the Regional
Administrator. The owner or operator shall comply with the plan once
the plan is submitted to the Regional Administrator. The owner or
operator shall amend the plan as requested or needed. The plan shall
include a description of the dust suppression methods for controlling
dust from the coal handling and storage facilities, ash handling,
storage and landfilling, and road sweeping activities. Within 18 months
of promulgation of this paragraph (j) each owner or operator shall not
emit dust with opacity greater than 20 percent from any crusher,
grinding mill, screening operation, belt conveyor, or truck loading or
unloading operation.
[FR Doc. 2010-26262 Filed 10-18-10; 8:45 am]
BILLING CODE 6560-50-P