[Federal Register Volume 84, Number 188 (Friday, September 27, 2019)]
[Rules and Regulations]
[Pages 51056-51060]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2019-19877]
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ENVIRONMENTAL PROTECTION AGENCY
40 CFR Part 52
[EPA-R06-OAR-2015-0189; FRL-9997-88-Region 6]
Promulgation of Air Quality Implementation Plans; State of
Arkansas; Regional Haze Federal Implementation Plan Revisions;
Withdrawal of Portions of the Federal Implementation Plan
AGENCY: Environmental Protection Agency (EPA).
ACTION: Final rule.
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SUMMARY: The Environmental Protection Agency (EPA) is amending a
Federal Implementation Plan (FIP) that addresses regional haze for the
first planning period for Arkansas as it applies to the best available
retrofit technology (BART) requirements for sulfur dioxide
(SO2) and particulate matter (PM) for seven electric
generating units (EGUs) in Arkansas and the SO2 requirements
under the reasonable progress provisions. These portions of the FIP
will be replaced by the portions of a revision to the Arkansas State
Implementation Plan (SIP) that we are taking final action to approve in
a separate rulemaking that is published elsewhere in this issue of the
Federal Register.
DATES: This final rule is effective October 28, 2019.
ADDRESSES: The EPA has established a docket for this action under
Docket No. EPA-R06-OAR-2015-0189. All documents in the dockets are
listed on the http://www.regulations.gov website. Although listed in
the index, some information is not publicly available, e.g.,
Confidential Business Information or other information whose disclosure
is restricted by statute. Certain other material, such as copyrighted
material, is not placed on the internet and will be publicly available
only in hard copy form. Publicly available docket materials are
available either electronically through http://www.regulations.gov or
in hard copy at the EPA Region 6, 1201 Elm Street, Suite 500, Dallas,
Texas 75270-2102.
FOR FURTHER INFORMATION CONTACT: Dayana Medina, (214) 665-7241;
[email protected].
SUPPLEMENTARY INFORMATION: Throughout this document wherever ``we,''
``us,'' or ``our'' is used, we mean the EPA.
Table of Contents
I. What is the background for this action?
II. What Final action is EPA taking?
III. Responses to Comments Received
IV. Statutory and Executive Order Reviews
I. What is the background for this action?
Arkansas submitted a SIP revision on September 9, 2008, to address
the requirements of the first regional haze implementation period. On
August 3, 2010, Arkansas submitted a SIP revision with mostly non-
substantive revisions to Arkansas Pollution Control and Ecology
Commission (APCEC) Regulation 19, Chapter 15.\1\ On September 27, 2011,
the State submitted supplemental information to clarify several aspects
of the September 9, 2008 submittal. We are hereafter referring to these
regional haze submittals collectively as the ``2008 Arkansas Regional
Haze SIP.'' On March 12, 2012, we partially approved and partially
disapproved the 2008 Arkansas Regional Haze SIP.\2\ On September 27,
2016, in accordance with Section 110(c)(1) of the CAA, we promulgated a
FIP (the Arkansas Regional Haze FIP) addressing the disapproved
portions of
[[Page 51057]]
the 2008 Arkansas Regional Haze SIP.\3\ Among other things, the FIP
established SO2, nitrogen oxide (NOX), and PM
emission limits under the BART requirements for nine units at six
facilities: Arkansas Electric Cooperative Corporation (AECC) Bailey
Plant Unit 1; AECC McClellan Plant Unit 1; the American Electric Power/
Southwestern Electric Power Company (AEP/SWEPCO) Flint Creek Plant
Boiler No. 1; Entergy Arkansas, Inc. (Entergy) Lake Catherine Plant
Unit 4; Entergy White Bluff Plant Units 1 and 2; Entergy White Bluff
Auxiliary Boiler; and the Domtar Ashdown Mill Power Boilers No. 1 and
2. The FIP also established SO2 and NOX emission
limits under the reasonable progress requirements for Entergy
Independence Units 1 and 2.
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\1\ The September 9, 2008 SIP submittal included APCEC
Regulation 19, Chapter 15, which is the state regulation that
identified the BART-eligible and subject-to-BART sources in Arkansas
and established BART emission limits for subject-to-BART sources.
The August 3, 2010 SIP revision did not revise Arkansas' list of
BART-eligible and subject-to-BART sources or revise any of the BART
requirements for affected sources. Instead, it included mostly non-
substantive revisions to the state regulation.
\2\ 77 FR 14604.
\3\ 81 FR 66332; see also 81 FR 68319 (October 4, 2016)
(correction).
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Following the issuance of the Arkansas Regional Haze FIP, the State
of Arkansas and several industry parties filed petitions for
reconsideration and a motion for an administrative stay of the final
rule.\4\ On April 14, 2017, we announced our decision to reconsider
several elements of the FIP, as follows: appropriate compliance dates
for the NOX emission limits for Flint Creek Boiler No. 1,
White Bluff Units 1 and 2, and Independence Units 1 and 2; the low-load
NOX emission limits applicable to White Bluff Units 1 and 2
and Independence Units 1 and 2 during periods of operation at less than
50 percent of the units' maximum heat input rating; the SO2
emission limits for White Bluff Units 1 and 2; and the compliance dates
for the SO2 emission limits for Independence Units 1 and
2.\5\
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\4\ See the docket associated with this proposed rulemaking for
a copy of the petitions for reconsideration and administrative stay
submitted by the State of Arkansas; Entergy Arkansas Inc., Entergy
Mississippi Inc., and Entergy Power LLC (collectively ``Entergy'');
AECC; and the Energy and Environmental Alliance of Arkansas (EEAA).
\5\ Letter from E. Scott Pruitt, Administrator, EPA, to Nicholas
Jacob Bronni and Jamie Leigh Ewing, Arkansas Attorney General's
Office (April 14, 2017). A copy of this letter is included in the
docket, https://www.regulations.gov/document?D=EPA-R06-OAR-2015-0189-0240.
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EPA also published a notice in the Federal Register on April 25,
2017, which administratively stayed the effectiveness of the
NOX compliance dates in the FIP for the Flint Creek, White
Bluff, and Independence units, as well as the compliance dates for the
SO2 emission limits for the White Bluff and Independence
units for a period of 90 days.\6\ On July 13, 2017, the EPA published a
notice proposing to extend the NOX compliance dates for
Flint Creek Boiler No. 1, White Bluff Units 1 and 2, and Independence
Units 1 and 2, by 21 months, to January 27, 2020.\7\ However, EPA did
not take final action on the July 13, 2017 proposed rule because on
July 12, 2017, Arkansas submitted a proposed SIP revision with a
request for parallel processing (Arkansas Regional Haze NOX
SIP revision or Arkansas NOX SIP revision). The State's
proposed revision addressed the NOX BART requirements for
Bailey Unit 1, McClellan Unit 1, Flint Creek Boiler No. 1, Lake
Catherine Unit 4, White Bluff Units 1 and 2, and White Bluff Auxiliary
Boiler, as well as the reasonable progress requirements with respect to
NOX. We processed this proposed SIP revision in parallel
with the state's SIP approval process and, in a proposed rule published
in the Federal Register on September 11, 2017, we proposed approval of
the Arkansas Regional Haze NOX SIP revision and withdrawal
of the corresponding parts of the Arkansas Regional Haze FIP.\8\ On
October 31, 2017, we received ADEQ's final Regional Haze NOX
SIP revision addressing NOX BART for EGUs and the reasonable
progress requirements with respect to NOX for the first
implementation period. On February 12, 2018, we finalized our approval
of the Arkansas Regional Haze NOX SIP revision and our
withdrawal of the corresponding parts of the FIP.\9\
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\6\ 82 FR 18994.
\7\ 82 FR 32284.
\8\ 82 FR 42627.
\9\ 83 FR 5927 and 83 FR 5915 (February 12, 2018).
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On August 8, 2018, Arkansas submitted another SIP revision
(Arkansas Regional Haze SO2 and PM SIP revision or Phase II
SIP revision) addressing all remaining disapproved parts of the 2008
Regional Haze SIP, with the exception of the BART and associated long-
term strategy requirements for the Domtar Ashdown Mill Power Boilers
No. 1 and 2. The Phase II SIP revision also included a discussion on
Arkansas' interstate visibility transport requirements. In a proposed
rule published in the Federal Register on November 30, 2018, we
proposed approval of a portion of the SIP revision and we also proposed
to withdraw the parts of the FIP corresponding to our proposed
approvals.\10\ We stated in our proposed rule that we intended to
propose action on the portion of the SIP revision discussing the
interstate visibility transport requirements in a future proposed
rulemaking. Since we proposed to withdraw certain portions of the FIP,
we also proposed to revise the numbering of certain paragraphs under
section 40 CFR 52.173 of the FIP. In a final action being published
separately in today's Federal Register, we are taking final action to
approve the Arkansas Regional Haze SO2 and PM SIP revision.
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\10\ 83 FR 62204 (November 30, 2018).
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The background for this final rule and the separate final action
also being published today that approves the Arkansas Regional Haze
SO2 and PM SIP revision is also discussed in detail in our
November 30, 2018 proposal.\11\ The comment period was open for 30
days, and we received comments from four commenters in response to our
proposed action.
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\11\ 83 FR 62204.
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II. What final action is EPA taking?
We are withdrawing the majority of the Arkansas Regional Haze FIP
that we promulgated on September 27, 2016. Specifically, we are
withdrawing the following components of the FIP at 40 CFR 52.173: The
SO2 and PM BART emission limits for Bailey Unit 1; the
SO2 and PM BART emission limits for McClellan Unit 1; the
SO2 BART emission limit for Flint Creek Boiler No. 1; the
SO2 BART emission limits for White Bluff Units 1 and 2; the
SO2 and PM BART emission limits for the White Bluff
Auxiliary Boiler; the prohibition on burning fuel oil at Lake Catherine
Unit 4; and the SO2 emission limits for Independence Units 1
and 2 under the reasonable progress provisions. Therefore, we are
removing these SO2 and PM emission limitations and
associated requirements for Arkansas EGUs from 40 CFR 52.173(c), and as
of the effective date of this final rule they will no longer apply to
the nine aforementioned units. Since we are withdrawing certain
portions of the FIP, we are also revising the numbering of certain
paragraphs under section 40 CFR 52.173 of the FIP. Our renumbering of
these paragraphs is non-substantive in nature. The provisions of the
Arkansas Regional Haze FIP addressing the Domtar Ashdown Mill are
unaffected by this action and the Domtar Ashdown Mill is the only
remaining facility subject to the FIP.
As explained in our November 30, 2018 proposal,\12\ this action is
based on our separate action being published in today's Federal
Register to approve the Arkansas Regional Haze SO2 and PM
SIP revision submitted to us on August 8, 2018. In that separate
action, EPA is making the determination that the Arkansas Regional Haze
SO2 and PM SIP revision is approvable because the plan's
provisions meet the applicable requirements of the CAA and EPA
implementing regulations. EPA is
[[Page 51058]]
finalizing this action under section 110 and part C of the Act.
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\12\ 83 FR 62204.
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III. Responses to Comments Received
We received several comment letters concerning our proposed action,
which included both our proposed approval of the portions of the Phase
II SIP revision listed in the previous section and proposed withdrawal
of the FIP provisions addressing the requirements for which we were
proposing SIP approval. EPA did not receive any comments specifically
on withdrawal of the FIP provisions; rather, the comments addressed
EPA's proposed approval of the SIP provisions that would replace the
FIP. Therefore, we have responded to all relevant comments in response
to our proposed action in a separate, final notice published elsewhere
in this issue of the Federal Register that approves the Arkansas
Regional Haze SO2 and PM SIP revision and/or in a separate
document titled the ``Arkansas Regional Haze Phase II SIP Revision
Response to Comments,'' which can be found in the docket associated
with this final rulemaking.\13\ Copies of the comments are also
available in the docket for this rulemaking.
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\13\ Please see Docket No. EPA-R06-OAR-2015-0189 in the
regulations.gov website.
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V. Statutory and Executive Order Reviews
Additional information about these statutes and Executive Orders
can be found at http://www2.epa.gov/lawsregulations/laws-and-executive-orders.
A. Executive Order 12866: Regulatory Planning and Review and Executive
Order 13563: Improving Regulation and Regulatory Review
This action is not a significant regulatory action and was
therefore not submitted to the Office of Management and Budget (OMB)
for review. This final rule revises a FIP to withdraw source-specific
SO2 and PM emission limits for only six individually
identified facilities in Arkansas and is therefore not a rule of
general applicability.
B. Executive Order 13771: Reducing Regulations and Controlling
Regulatory Costs
This action is not an Executive Order 13771 regulatory action
because this action is not significant under Executive Order 12866.
C. Paperwork Reduction Act (PRA)
This action does not impose an information collection burden under
the provisions of the PRA. Burden is defined at 5 CFR 1320.3(b). This
final rule revises a FIP to withdraw source-specific SO2 and
PM emission limits for six individually identified facilities in
Arkansas.
D. Regulatory Flexibility Act (RFA)
I certify that this final action will not have a significant
economic impact on a substantial number of small entities under the
RFA. This final action will not impose any requirements on small
entities. This final action revises a FIP to withdraw source-specific
SO2 and PM emission limits that apply to six individually
identified power plants in Arkansas.
E. Unfunded Mandates Reform Act (UMRA)
This action does not contain any unfunded mandate as described in
UMRA, 2 U.S.C. 1531-1538, and does not significantly or uniquely affect
small governments. This action does not impose additional requirements
beyond those imposed by state law. Accordingly, no additional costs to
State, local, or tribal governments, or to the private sector, will
result from this action.
F. Executive Order 13132: Federalism
This action does not have federalism implications. It will not have
substantial direct effects on the states, on the relationship between
the national government and the states, or on the distribution of power
and responsibilities among the various levels of government.
G. Executive Order 13175: Consultation and Coordination With Indian
Tribal Governments
This action does not have tribal implications, as specified in
Executive Order 13175, because this partial FIP withdrawal does not
apply on any Indian reservation land or in any other area where the EPA
or an Indian tribe has demonstrated that a tribe has jurisdiction, and
will not impose substantial direct costs on tribal governments or
preempt tribal law. This final action revises a FIP to withdraw source-
specific SO2 and PM emission limits that apply to six
individually identified power plants in Arkansas. There are no Indian
reservation lands in Arkansas. Thus, Executive Order 13175 does not
apply to this action.
H. Executive Order 13045: Protection of Children From Environmental
Health Risks and Safety Risks
The EPA interprets Executive Order 13045 as applying only to those
regulatory actions that concern environmental health or safety risks
that the EPA has reason to believe may disproportionately affect
children, per the definition of ``covered regulatory action'' in
section 2-202 of the Executive Order. This action is not subject to
Executive Order 13045 because it does not concern an environmental
health risk or safety risk.
I. Executive Order 13211: Actions That Significantly Affect Energy
Supply, Distribution, or Use
This action is not subject to Executive Order 13211, because it is
not a significant regulatory action under Executive Order 12866.
J. National Technology Transfer and Advancement Act (NTTAA)
This rulemaking does not involve technical standards.
K. Executive Order 12898: Federal Actions To Address Environmental
Justice in Minority Populations and Low-Income Populations
The EPA believes the human health or environmental risk addressed
by this action will not have potentially disproportionately high and
adverse human health or environmental effects on minority, low-income
or indigenous populations.
L. Determination Under Section 307(d)
Pursuant to CAA section 307(d)(1)(B), this action is subject to the
requirements of CAA section 307(d), as it revises a FIP under CAA
section 110(c).
M. Congressional Review Act (CRA)
This rule is exempt from the CRA because it is a rule of particular
applicably. EPA is not required to submit a rule report regarding this
action under section 801 because this is a rule of particular
applicability that only affects six individually identified facilities
in Arkansas.
N. Petitions for Judicial Review
Under section 307(b)(1) of the Clean Air Act, petitions for
judicial review of this action must be filed in the United States Court
of Appeals for the appropriate circuit by November 26, 2019. Filing a
petition for reconsideration by the Administrator of this final rule
does not affect the finality of this rule for the purposes of judicial
review nor does it extend the time within which a petition for judicial
review may be filed, and shall not postpone the effectiveness of such
rule or action. This action may not be challenged later in proceedings
to enforce its requirements (see section 307(b)(2)).
[[Page 51059]]
List of Subjects in 40 CFR Part 52
Environmental protection, Air pollution control, Best available
retrofit technology, Incorporation by reference, Intergovernmental
relations, Ozone, Particulate Matter, Regional haze, Reporting and
recordkeeping requirements, Sulfur Dioxide, Visibility.
Dated: September 9, 2019.
Andrew R. Wheeler,
Administrator.
Title 40, chapter I, of the Code of Federal Regulations is amended
as follows:
PART 52--APPROVAL AND PROMULGATION OF IMPLEMENTATION PLANS
0
1. The authority citation for part 52 continues to read as follows:
Authority: 42 U.S.C. 7401 et seq.
Subpart E--Arkansas
0
2. Section 52.173 is amended:
0
a. By revising paragraphs (c) introductory text and (c)(1);
0
b. In paragraph (c)(2), by revising the definition of ``Boiler-
operating-day'';
0
c. By removing paragraphs (c)(3) through (12) and (22) through (24);
0
d. By redesignating paragraphs (c)(13) through (21) as paragraphs
(c)(3) through (11) and paragraphs (c)(25) through (27) as paragraphs
(c)(12) through (14); and
0
f. By revising newly redesignated paragraphs (c)(4), (5), (7), (8),
(10), and (11).
The revisions read as follows:
Sec. 52.173 Visibility protection.
* * * * *
(c) Federal implementation plan for regional haze. Requirements for
Domtar Ashdown Paper Mill Power Boilers No. 1 and 2 affecting
visibility.
(1) Applicability. The provisions of this section shall apply to
each owner or operator, or successive owners or operators of the
sources designated as Domtar Ashdown Paper Mill Power Boilers No. 1 and
2.
(2) * * *
Boiler-operating-day means a 24-hr period between 6 a.m. and 6 a.m.
the following day during which any fuel is fed into and/or combusted at
any time in the power boiler.
* * * * *
(4) Compliance dates for Domtar Ashdown Mill Power Boiler No. 1.
The owner or operator of the boiler must comply with the SO2
and NOX emission limits listed in paragraph (c)(3) of this
section by November 28, 2016.
(5) Compliance determination and reporting and recordkeeping
requirements for Domtar Ashdown Paper Mill Power Boiler No. 1. (i)(A)
SO2 emissions resulting from combustion of fuel oil shall be
determined by assuming that the SO2 content of the fuel
delivered to the fuel inlet of the combustion chamber is equal to the
SO2 being emitted at the stack. The owner or operator must
maintain records of the sulfur content by weight of each fuel oil
shipment, where a ``shipment'' is considered delivery of the entire
amount of each order of fuel purchased. Fuel sampling and analysis may
be performed by the owner or operator, an outside laboratory, or a fuel
supplier. All records pertaining to the sampling of each shipment of
fuel oil, including the results of the sulfur content analysis, must be
maintained by the owner or operator and made available upon request to
EPA and ADEQ representatives. SO2 emissions resulting from
combustion of bark shall be determined by using the following site-
specific curve equation, which accounts for the SO2
scrubbing capabilities of bark combustion:
Y= 0.4005 * X--0.2645
Where:
Y= pounds of sulfur emitted per ton of dry fuel feed to the boiler.
X= pounds of sulfur input per ton of dry bark.
(B) The owner or operator must confirm the site-specific curve
equation through stack testing. By October 27, 2017, the owner or
operator must provide a report to EPA showing confirmation of the site
specific-curve equation accuracy. Records of the quantity of fuel input
to the boiler for each fuel type for each day must be compiled no later
than 15 days after the end of the month and must be maintained by the
owner or operator and made available upon request to EPA and ADEQ
representatives. Each boiler-operating-day of the 30-day rolling
average for the boiler must be determined by adding together the pounds
of SO2 from that boiler-operating-day and the preceding 29
boiler-operating-days and dividing the total pounds of SO2
by the sum of the total number of boiler operating days (i.e., 30). The
result shall be the 30 boiler-operating-day rolling average in terms of
lb/day emissions of SO2. Records of the total SO2
emitted for each day must be compiled no later than 15 days after the
end of the month and must be maintained by the owner or operator and
made available upon request to EPA and ADEQ representatives. Records of
the 30 boiler-operating-day rolling averages for SO2 as
described in this paragraph (c)(5)(i) must be maintained by the owner
or operator for each boiler-operating-day and made available upon
request to EPA and ADEQ representatives.
(ii) If the air permit is revised such that Power Boiler No. 1 is
permitted to burn only pipeline quality natural gas, this is sufficient
to demonstrate that the boiler is complying with the SO2
emission limit under paragraph (c)(3) of this section. The compliance
determination requirements and the reporting and recordkeeping
requirements under paragraph (c)(5)(i) of this section would not apply
and confirmation of the accuracy of the site-specific curve equation
under paragraph (c)(5)(i)(B) of this section through stack testing
would not be required so long as Power Boiler No. 1 is only permitted
to burn pipeline quality natural gas.
(iii) To demonstrate compliance with the NOX emission
limit under paragraph (c)(3) of this section, the owner or operator
shall conduct stack testing using EPA Reference Method 7E, found at 40
CFR part 60, appendix A, once every 5 years, beginning 1 year from the
effective date of our final rule, which corresponds to October 27,
2017. Records and reports pertaining to the stack testing must be
maintained by the owner or operator and made available upon request to
EPA and ADEQ representatives.
(iv) If the air permit is revised such that Power Boiler No. 1 is
permitted to burn only pipeline quality natural gas, the owner or
operator may demonstrate compliance with the NOX emission
limit under paragraph (c)(3) of this section by calculating
NOX emissions using fuel usage records and the applicable
NOX emission factor under AP-42, Compilation of Air
Pollutant Emission Factors, section 1.4, Table 1.4-1. Records of the
quantity of natural gas input to the boiler for each day must be
compiled no later than 15 days after the end of the month and must be
maintained by the owner or operator and made available upon request to
EPA and ADEQ representatives. Records of the calculation of
NOX emissions for each day must be compiled no later than 15
days after the end of the month and must be maintained by the owner or
operator and made available upon request to EPA and ADEQ
representatives. Each boiler-operating-day of the 30-day rolling
average for the boiler must be determined by adding together the pounds
of NOX from that day and the preceding 29 boiler-operating-
days and dividing the total pounds of NOX by the sum of the
total number of hours during the same 30 boiler-operating-day period.
The result
[[Page 51060]]
shall be the 30 boiler-operating-day rolling average in terms of lb/hr
emissions of NOX. Records of the 30 boiler-operating-day
rolling average for NOX must be maintained by the owner or
operator for each boiler-operating-day and made available upon request
to EPA and ADEQ representatives. Under these circumstances, the
compliance determination requirements and the reporting and
recordkeeping requirements under paragraph (c)(5)(iii) of this section
would not apply.
* * * * *
(7) SO2 and NOX Compliance dates for Domtar Ashdown Mill Power
Boiler No. 2. The owner or operator of the boiler must comply with the
SO2 and NOX emission limits listed in paragraph
(c)(6) of this section by October 27, 2021.
(8) SO2 and NOX Compliance determination and reporting and
recordkeeping requirements for Domtar Ashdown Mill Power Boiler No. 2.
(i) NOX and SO2 emissions for each day shall be
determined by summing the hourly emissions measured in pounds of
NOX or pounds of SO2. Each boiler-operating-day
of the 30-day rolling average for the boiler shall be determined by
adding together the pounds of NOX or SO2 from
that day and the preceding 29 boiler-operating-days and dividing the
total pounds of NOX or SO2 by the sum of the
total number of hours during the same 30 boiler-operating-day period.
The result shall be the 30 boiler-operating-day rolling average in
terms of lb/hr emissions of NOX or SO2. If a
valid NOX pounds per hour or SO2 pounds per hour
is not available for any hour for the boiler, that NOX
pounds per hour shall not be used in the calculation of the 30 boiler-
operating-day rolling average for NOX. For each day, records
of the total SO2 and NOX emitted for that day by
the boiler must be maintained by the owner or operator and made
available upon request to EPA and ADEQ representatives. Records of the
30 boiler-operating-day rolling average for SO2 and
NOX for the boiler as described in this paragraph (c)(8)(i)
must be maintained by the owner or operator for each boiler-operating-
day and made available upon request to EPA and ADEQ representatives.
(ii) The owner or operator shall continue to maintain and operate a
CEMS for SO2 and NOX on the boiler listed in
paragraph (c)(6) of this section in accordance with 40 CFR 60.8 and
60.13(e), (f), and (h), and appendix B of 40 CFR part 60. The owner or
operator shall comply with the quality assurance procedures for CEMS
found in 40 CFR part 60. Compliance with the emission limits for
SO2 and NOX shall be determined by using data
from a CEMS.
(iii) Continuous emissions monitoring shall apply during all
periods of operation of the boiler listed in paragraph (c)(6) of this
section, including periods of startup, shutdown, and malfunction,
except for CEMS breakdowns, repairs, calibration checks, and zero and
span adjustments. Continuous monitoring systems for measuring
SO2 and NOX and diluent gas shall complete a
minimum of one cycle of operation (sampling, analyzing, and data
recording) for each successive 15-minute period. Hourly averages shall
be computed using at least one data point in each fifteen-minute
quadrant of an hour. Notwithstanding this requirement, an hourly
average may be computed from at least two data points separated by a
minimum of 15 minutes (where the unit operates for more than one
quadrant in an hour) if data are unavailable as a result of performance
of calibration, quality assurance, preventive maintenance activities,
or backups of data from data acquisition and handling system, and
recertification events. When valid SO2 or NOX
pounds per hour emission data are not obtained because of continuous
monitoring system breakdowns, repairs, calibration checks, or zero and
span adjustments, emission data must be obtained by using other
monitoring systems approved by the EPA to provide emission data for a
minimum of 18 hours in each 24-hour period and at least 22 out of 30
successive boiler operating days.
(iv) If the air permit is revised such that Power Boiler No. 2 is
permitted to burn only pipeline quality natural gas, this is sufficient
to demonstrate that the boiler is complying with the SO2
emission limit under paragraph (c)(6) of this section. Under these
circumstances, the compliance determination requirements under
paragraphs (c)(8)(i) through (iii) of this section would not apply to
the SO2 emission limit listed in paragraph (c)(6) of this
section.
(v) If the air permit is revised such that Power Boiler No. 2 is
permitted to burn only pipeline quality natural gas and the operation
of the CEMS is not required under other applicable requirements, the
owner or operator may demonstrate compliance with the NOX
emission limit under paragraph (c)(6) of this section by calculating
NOX emissions using fuel usage records and the applicable
NOX emission factor under AP-42, Compilation of Air
Pollutant Emission Factors, section 1.4, Table 1.4-1. Records of the
quantity of natural gas input to the boiler for each day must be
compiled no later than 15 days after the end of the month and must be
maintained by the owner or operator and made available upon request to
EPA and ADEQ representatives. Records of the calculation of
NOX emissions for each day must be compiled no later than 15
days after the end of the month and must be maintained and made
available upon request to EPA and ADEQ representatives. Each boiler-
operating-day of the 30-day rolling average for the boiler must be
determined by adding together the pounds of NOX from that
day and the preceding 29 boiler-operating-days and dividing the total
pounds of NOX by the sum of the total number of hours during
the same 30 boiler-operating-day period. The result shall be the 30
boiler-operating-day rolling average in terms of lb/hr emissions of
NOX. Records of the 30 boiler-operating-day rolling average
for NOX must be maintained by the owner or operator for each
boiler-operating-day and made available upon request to EPA and ADEQ
representatives. Under these circumstances, the compliance
determination requirements under paragraphs (c)(8)(i) through (iii) of
this section would not apply to the NOX emission limit.
* * * * *
(10) PM compliance dates for Domtar Ashdown Mill Power Boiler No.
2. The owner or operator of the boiler must comply with the PM BART
requirement listed in paragraph (c)(9) of this section by November 28,
2016.
(11) Alternative PM Compliance Determination for Domtar Ashdown
Paper Mill Power Boiler No. 2. If the air permit is revised such that
Power Boiler No. 2 is permitted to burn only pipeline quality natural
gas, this is sufficient to demonstrate that the boiler is complying
with the PM BART requirement under paragraph (c)(9) of this section.
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[FR Doc. 2019-19877 Filed 9-26-19; 8:45 am]
BILLING CODE 6560-50-P