[Federal Register Volume 85, Number 175 (Wednesday, September 9, 2020)]
[Rules and Regulations]
[Pages 55744-55780]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2020-15950]



[[Page 55743]]

Vol. 85

Wednesday,

No. 175

September 9, 2020

Part II





Environmental Protection Agency





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40 CFR Part 63





Mercury and Air Toxics Standards for Power Plants Electronic Reporting 
Revisions; Final Rule

  Federal Register / Vol. 85, No. 175 / Wednesday, September 9, 2020 / 
Rules and Regulations  

[[Page 55744]]


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ENVIRONMENTAL PROTECTION AGENCY

40 CFR Part 63

[EPA-HQ-OAR-2018-0794; FRL-10011-53-OAR]
RIN 2060-AU70


Mercury and Air Toxics Standards for Power Plants Electronic 
Reporting Revisions

AGENCY: Environmental Protection Agency (EPA).

ACTION: Final rule.

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SUMMARY: The U.S Environmental Protection Agency (EPA) is finalizing 
amendments to the electronic reporting requirements for the National 
Emission Standards for Hazardous Air Pollutants: Coal- and Oil-Fired 
Electric Utility Steam Generating Units (also known as the Mercury and 
Air Toxics Standards (MATS)). This action revises and streamlines the 
electronic data reporting requirements of MATS, increases data 
transparency by requiring use of one electronic reporting system 
instead of two separate systems, and provides enhanced access to MATS 
data. No new monitoring requirements are imposed by this final action; 
instead, this action reduces reporting burden, increases MATS data flow 
and usage, makes it easier for inspectors and auditors to assess 
compliance, and encourages wider use of continuous emissions monitoring 
systems (CEMS) for MATS compliance. In addition, this final action 
extends the current deadline for alternative electronic data submission 
via portable document format (PDF) files through December 31, 2023.

DATES: This final rule is effective on September 9, 2020.

ADDRESSES: The EPA has established a docket for this action under 
Docket ID No. EPA-HQ-OAR-2018-0794. All documents in the docket are 
listed on the https://www.regulations.gov/ website. Although listed, 
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 electronically 
through https://www.regulations.gov/. Out of an abundance of caution 
for members of the public and our staff, the EPA Docket Center and 
Reading Room was closed to the public, with limited exceptions, to 
reduce the risk of transmitting COVID-19. Our Docket Center staff will 
continue to provide remote customer service via email, phone, and 
webform. For further information and updates on EPA Docket Center 
services and the current status, please visit us online at https://www.epa.gov/dockets.

FOR FURTHER INFORMATION CONTACT: Mr. Barrett Parker, Sector Policies 
and Programs Division (D243-05), Office of Air Quality Planning and 
Standards, U.S. Environmental Protection Agency, Research Triangle 
Park, NC 27711; telephone number: (919) 541-5635; email address: 
[email protected]. For general information concerning MATS, 
contact Ms. Mary Johnson, Sector Policies and Programs Division (D243-
01), Office of Air Quality Planning and Standards, U.S. Environmental 
Protection Agency, Research Triangle Park, NC 27711; telephone number: 
(919) 541-5025; email address: [email protected]. For questions 
concerning the Emissions Collection and Monitoring Plan System (ECMPS) 
Client Tool and its implementation, contact Mr. Christopher Worley, 
Clean Air Markets Division, Mail Code 6204M, U.S. Environmental 
Protection Agency, 1200 Pennsylvania Ave. NW, Washington, DC 20460; 
telephone number: (202) 343-9531; email address: 
[email protected].

SUPPLEMENTARY INFORMATION: The information in this preamble is 
organized as follows:

Table of Contents

I. General Information
    A. Does this action apply to me?
    B. Where can I get a copy of this document and other related 
information?
    C. Judicial Review and Administrative Reconsideration
    D. What action is the Agency taking?
    E. What is the Agency's authority for taking this action?
    F. What are the incremental costs and benefits of this action?
II. Background
III. What is the scope of these amendments?
IV. What are the specific amendments to 40 CFR part 63, subpart 
UUUUU as a result of this action?
    A. Revisions to the Reporting Requirements of MATS
    B. Revisions to Appendix A
    C. Revisions to Appendix B
    D. Addition to Appendix C
    E. Addition to Appendix D
    F. Addition to Appendix E
V. Revisions to Other Rule Text
VI. Statutory and Executive Order Reviews
    A. Executive Order 12866: Regulatory Planning and Review and 
Executive Order 13563: Improving Regulation and Regulatory Review
    B. Executive Order 13771: Reducing Regulations and Controlling 
Regulatory Costs
    C. Paperwork Reduction Act (PRA)
    D. Regulatory Flexibility Act (RFA)
    E. Unfunded Mandates Reform Act (UMRA)
    F. Executive Order 13132: Federalism
    G. Executive Order 13175: Consultation and Coordination With 
Indian Tribal Governments
    H. Executive Order 13045: Protection of Children From 
Environmental Health Risks and Safety Risks
    I. Executive Order 13211: Actions Concerning Regulations That 
Significantly Affect Energy Supply, Distribution, or Use
    J. National Technology Transfer and Advancement Act (NTTAA)
    K. Executive Order 12898: Federal Actions To Address 
Environmental Justice in Minority Populations and Low-Income 
Populations
    L. Congressional Review Act (CRA)

I. General Information

A. Does this action apply to me?

    Categories and entities potentially affected by this action 
include:

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                                                 Examples of potentially
            Category             NAICS code \1\     regulated entities
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Industry.......................          221112  Fossil fuel-fired
                                                  electric utility steam
                                                  generating units
                                                  (EGUs).
Federal government.............      \2\ 221122  Fossil fuel-fired EGUs
                                                  owned by the federal
                                                  government.
State/local/tribal government..      \2\ 221122  Fossil fuel-fired EGUs
                                                  owned by
                                                  municipalities.
                                         921150  Fossil fuel-fired EGUs
                                                  in Indian country.
------------------------------------------------------------------------
\1\ North American Industry Classification System.
\2\ Federal, state, or local government-owned and operated
  establishments are classified according to the activity in which they
  are engaged.

    This table is not intended to be exhaustive, but rather provides a 
guide for readers regarding entities likely to be regulated by this 
action. This table lists the types of entities that the EPA is now 
aware could potentially be regulated by this action. Other types of 
entities not listed in the table could also be regulated. To determine 
whether your

[[Page 55745]]

entity is regulated by this action, you should carefully examine the 
applicability criteria in 40 CFR 63.9981 of the rule. If you have 
questions regarding the applicability of this action to a particular 
entity, consult either the air permitting authority for the entity or 
your EPA Regional representative as listed in 40 CFR 63.13.

B. Where can I get a copy of this document and other related 
information?

    In addition to being available in the docket, an electronic copy of 
this final action will also be available on the internet. Following 
signature by the EPA Administrator, the EPA will post a copy of this 
final action at: https://www.epa.gov/mats/regulatory-actions-final-mercury-and-air-toxics-standards-mats-power-plants. Following 
publication in the Federal Register, the EPA will post the Federal 
Register version and key technical documents at this same website.

C. Judicial Review and Administrative Reconsideration

    Under Clean Air Act (CAA) section 307(b)(1), judicial review of 
this final action is available only by filing a petition for review in 
the United States Court of Appeals for the District of Columbia Circuit 
by November 9, 2020. Under CAA section 307(b)(2), the requirements 
established by this final rule may not be challenged separately in any 
civil or criminal proceedings brought by the EPA to enforce the 
requirements.
    Section 307(d)(7)(B) of the CAA further provides that only an 
objection to a rule or procedure which was raised with reasonable 
specificity during the period for public comment (including any public 
hearing) may be raised during judicial review. This section also 
provides a mechanism for the EPA to reconsider the rule if the person 
raising an objection can demonstrate to the Administrator that it was 
impracticable to raise such objection within the period for public 
comment or if the grounds for such objection arose after the period for 
public comment (but within the time specified for judicial review) and 
if such objection is of central relevance to the outcome of the rule. 
Any person seeking to make such a demonstration should submit a 
Petition for Reconsideration to the Office of the Administrator, U.S. 
Environmental Protection Agency, Room 3000, WJC South Building, 1200 
Pennsylvania Ave. NW, Washington, DC 20460, with a copy to both the 
person(s) listed in the preceding FOR FURTHER INFORMATION CONTACT 
section, and the Associate General Counsel for the Air and Radiation 
Law Office, Office of General Counsel (Mail Code 2344A), U.S. 
Environmental Protection Agency, 1200 Pennsylvania Ave. NW, Washington, 
DC 20460.

D. What action is the Agency taking?

    The EPA is finalizing this rule to streamline the electronic data 
reporting requirements of MATS; to increase data transparency by making 
more of the MATS data available in Extensible Markup Language (XML) 
format; and to amend the reporting and recordkeeping requirements 
associated with performance stack tests, particulate matter (PM) and 
hydrogen chloride (HCl) CEMS, and PM continuous parameter monitoring 
systems (CPMS).

E. What is the Agency's authority for taking this action?

    The Agency's authority for taking this action is found at 42 U.S.C. 
7401 et seq.

F. What are the incremental costs and benefits of this action?

    As discussed in section VI.C of this preamble, this action is 
expected to reduce overall annual source burden by 11,000 hours per 
year, which when monetized is $15,079,000.

II. Background

    These amendments revise the recordkeeping and reporting 
requirements of the MATS rule, in response to concerns raised by the 
regulated community. The MATS rule originally required affected EGU 
owners or operators to report MATS rule emissions and compliance 
information electronically using two data systems. See 40 CFR 63.10031 
(77 FR 9304, February 16, 2012). Paragraph (a) of 40 CFR 63.10031 
required EGU owners or operators that demonstrate compliance by 
continuously monitoring mercury (Hg) and/or HCl and/or hydrogen 
fluoride (HF) emissions to use the ECMPS Client Tool to submit 
monitoring plan information, quality assurance (QA) test results, and 
hourly emissions data in accordance with appendices A and B to subpart 
UUUUU of 40 CFR part 63. Paragraph (f) of 40 CFR 63.10031 required 
performance stack test results, performance evaluations of Hg, HCl, HF, 
sulfur dioxide (SO2), and PM CEMS, 30-boiler operating day 
rolling average values for certain parameters, Notifications of 
Compliance Status, and semiannual compliance reports to be submitted to 
the EPA's WebFIRE database via the Compliance and Emissions Data 
Reporting Interface (CEDRI).
    Subsequent to the publication of the MATS rule, stakeholders 
suggested to the EPA that the MATS rule electronic reporting burden 
could be significantly reduced if all of the required information were 
reported to one data system instead of two. The stakeholders also 
suggested that using one data system would benefit the EPA and the 
public in their review of MATS rule data, because the information would 
be reported in a consistent format. In view of these considerations, 
the stakeholders urged the EPA to consider amending the MATS rule to 
require all of the data to be reported through the ECMPS, a familiar 
data system that most EGU owners or operators have been using since 
2009, to meet the electronic reporting requirements of the Acid Rain 
Program.
    After careful consideration of the stakeholders' recommendations, 
the EPA concluded that the increased transparency of the emissions data 
and the reduction in reporting burden that could be achieved through 
the use of a single data system are consistent with Agency priorities. 
As a result, late in 2014, the EPA decided to take the necessary steps 
to require all of the electronic reports required by the MATS rule to 
be submitted through the ECMPS Client Tool. Those steps would include 
revising the MATS rule, modifying the ECMPS Client Tool, creating a 
detailed set of reporting instructions, and beta testing the modified 
software. Recognizing that insufficient time was available to complete 
these tasks before the initial compliance date for the MATS rule (April 
16, 2015), the Agency embarked on a two-phased approach to complete 
them.
    The first phase was completed when the EPA published a final rule 
requiring EGU owners or operators to suspend temporarily (until April 
16, 2017) the use of the CEDRI interface as the means of submitting the 
reports described in 40 CFR 63.10031(f), (f)(1), (2), and (4), and to 
use the ECMPS Client Tool to submit PDF versions of these reports on an 
interim basis (see 80 FR 15510, March 24, 2015). The specific reports 
required to be submitted as PDF files included: Performance stack test 
reports containing enough information to assess compliance and to 
demonstrate that the testing was done properly; relative accuracy test 
audit (RATA) reports for SO2, HCl, HF, and Hg CEMS; RATA 
reports for Hg sorbent trap monitoring systems; response correlation 
audit (RCA) and relative response audit (RRA) reports for PM CEMS; 30-
boiler operating day rolling average reports for PM CEMS, PM CPMS, and 
approved hazardous air pollutants (HAP) metals CEMS; Notifications of 
Compliance Status; and semiannual compliance

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reports. Section 63.10031(f)(6) of the March 24, 2015, final rule 
required each PDF version of a submitted interim report to include 
information that identifies the facility (name and address), the EGU(s) 
to which the report applies, the applicable rule citations, and other 
information. The rule further specified that in the event that 
implementation of the single data system initiative was not completed 
by April 16, 2017, the electronic reporting of MATS data would revert 
to the original two systems approach on and after that date.
    In the preamble to the March 24, 2015, final rule, the EPA outlined 
the second phase of the single data system initiative, to be executed 
during the interim PDF reporting period. In phase two: (1) The Agency 
would publish a direct final rule, requiring MATS-affected sources to 
use the ECMPS Client Tool to submit all required reports; and (2) a 
detailed set of reporting instructions would be developed and ECMPS 
would be modified to receive and process the data.
    Considering the magnitude of the rule changes that would be 
required to execute phase two, coupled with the need to specify data 
elements to be reported electronically for PM CEMS, PM CPMS, and HCl 
CEMS, the Agency decided to provide stakeholders an opportunity to 
review and comment on the proposed changes. The EPA issued the proposed 
rule on September 29, 2016.\1\ The comment period for the 2016 proposal 
(or ``previous proposal'') was scheduled to close on October 31, 2016, 
but it was subsequently extended until November 15, 2016, in response 
to requests from several stakeholders for an extension.
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    \1\ 81 FR 67062, September 29, 2016.
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    Commenters were generally supportive of the initiative to simplify 
and streamline the MATS reporting requirements and to use the ECMPS 
Client Tool as the single MATS rule reporting system. However, they 
expressed serious concerns about the proposal to extend the interim PDF 
reporting process from April 16, 2017, to December 31, 2017. Although 
they favored an extension of the PDF reporting, they were unanimous in 
asserting that the proposed end date of December 31, 2017, would not 
allow enough time to finalize the rule, develop the necessary XML 
reporting formats and reporting instructions, and reprogram the ECMPS 
Client Tool. In addition, two data acquisition and handling system 
vendors stated that more time would be needed for them to adapt to the 
proposed changes and to develop the reporting software for their 
customers. Some of the commenters recommended that the EPA should 
extend the interim PDF reporting process through calendar year 2019; 
others suggested that the process should be extended for 6 to 8 
calendar quarters after finalization of the rule.
    In view of these considerations, on April 6, 2017, the EPA 
published a final rule extending the interim PDF file reporting process 
through June 30, 2018 (82 FR 16736). Technical corrections to appendix 
A were also included in the rule package. The rule went into effect on 
April 6, 2017. As the Agency was unable to complete the e-reporting 
provisions, another extension to the interim PDF file reporting 
process--through June 30, 2020--was promulgated on July 2, 2018 (83 FR 
30879).
    The Agency continued to develop the remaining electronic reporting 
and recordkeeping requirements, considering the comments received on 
the September 29, 2016 (81 FR 67062) proposal. When that effort was 
complete, rather than finalizing those requirements, the Agency decided 
to again provide stakeholders with an opportunity to review and comment 
on the requirements, so the Agency issued a proposal with those 
requirements on April 10, 2020 (85 FR 20342).
    Thirty-five comment letters were received, and they are available 
in the docket. Many of those comments were similar to comments 
submitted before in other proposals and have been addressed previously. 
Responses for the comments on this action are included in the Response 
to Comments document which is also available in the docket. Significant 
comments can be sorted into eight groups; their general descriptions 
and responses follow.
    1. Comments received on other MATS regulatory actions, e.g., 
removal of the appropriate and necessary determination, are not 
relevant for this action and were not addressed. Likewise, comments 
regarding other regulatory actions, e.g., insecticides and pesticides, 
are not relevant for this action and were not addressed.
    2. A majority of commenters supported extending the use of PDF 
reporting until January 2024. Many industry commenters suggested 
splitting the package so the extension could be finalized, and more 
time could be spent on reviewing the other portions of the package. The 
Agency is not splitting the package and appreciates the support for the 
extension until the ECMPS Client Tool is reprogrammed and ready for 
use. The Agency sees no need for additional time to comment on the 
proposed revisions, as those revisions have been available for review 
and comment for over 3 years--since the September 29, 2016, proposal.
    3. Commenters sought clarification on the conditions that would 
cause monitoring downtime to be considered a deviation, and the 
regulation provides that clarification.
    4. Industry commenters sought to have consistent application of 
grace periods and ongoing QA check periods (based on operating quarters 
only) for PM CEMS and PM CPMS; however, these instruments differ from 
other CEMS because except for the annual testing, there is no other 
time when the monitoring system is compared to a certified reference 
method value to determine accuracy. This difference means that 
techniques allowing for additional periods before testing is required 
puts EGU owners or operators, as well as the environment, at additional 
risk of elevated emissions during such periods. Due to this difference, 
and its potential effects, the regulation will not provide grace 
periods beyond 1 calendar quarter or ongoing QA checks based on 
operating quarters only.
    5. Commenters sought clarification on Hg low-emitting EGU (LEE) 
testing calculations, and the regulation provides such clarification in 
40 CFR 63.10005(h)(3)(iii).
    6. Some commenters continue to assert that data elements in 
appendix E are duplicative, but as described before, those data 
elements are already required and represent the minimum bits of 
information needed to ensure smooth operation of an electronic 
reporting system. Even so, clarifications from already-mentioned 
deviation and monitoring downtime circumstances, as well as for 
reporting span values and fuel usage, have been provided in appendix E.
    7. One commenter asked the Agency to reconsider allowing the use of 
alternate semi-annual reporting submission dates established by 
operating permit programs, at least until the ECMPS Client Tool is 
operational; the Agency agrees that this flexibility should be 
maintained during the extension period, and the rule has been revised 
to allow use of such alternate semi-annual reporting dates.
    8. Finally, some commenters requested continued engagement with 
stakeholders as the new ECMPS Client Tool software is developed and 
tested. Consistent with previous ECMPS reporting instructions changes 
and the implementation of previous MATS reporting changes, the Agency 
will

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provide draft reporting instructions and XML schema documentation prior 
to implementation and engage stakeholders during the development and 
testing of software.
    This action finalizes an extension of the interim PDF reporting 
process through December 31, 2023, and finalizes the remaining needed 
amendments to the MATS rule on electronic reporting. Note that these 
amendments were developed after consideration of the comments received 
on the September 29, 2016, and April 10, 2020, proposals. III. What is 
the scope of these amendments?
    This action amends the reporting requirements in 40 CFR 63.10031 of 
the MATS regulation, and, for consistency with those changes, amends 
related text in 40 CFR part 63, subpart UUUUU; specifically, 40 CFR 
63.10000, 63.10005, 63.10009, 63.10010, 63.10011, 63.10020, 63.10021, 
63.10030, 63.10032, 63.10042, and Tables 3, 8, and 9. In addition, the 
recordkeeping and reporting sections of appendices A and B are amended 
\2\ and three new appendices are added to the rule, i.e., appendices C, 
D, and E. Instead of using the electronic reporting tool (ERT) to 
submit some of the MATS data via CEDRI and submitting the remainder 
through the ECMPS Client Tool, as was required by the original MATS 
rule, this action allows EGU owners or operators to use the ECMPS 
Client Tool to report all of the required information in XML and PDF 
files.
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    \2\ In 2015, the EPA published a technology-neutral performance 
specification and associated QA test procedures for HCl monitors 
(see Performance Specification 18 (PS 18) and Procedure 6 in 80 FR 
38628, July 7, 2015). That rule added certification and QA test 
requirements for sources electing to monitor HCl according to PS 18 
and Procedure 6. This action requires the results of the appendix B 
certification and QA tests to be reported electronically for periods 
beginning on January 1, 2024.
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IV. What are the specific amendments to 40 CFR part 63, subpart UUUUU 
as a result of this action?

    The amendments to 40 CFR part 63, subpart UUUUU are discussed in 
detail in the paragraphs below.

A. Revisions to the Reporting Requirements of MATS

    The reporting requirements of MATS are amended as follows:
    (1) The ECMPS Client Tool is the exclusive data system for MATS 
reporting, in lieu of using both ECMPS and the CEDRI.
    (2) The interim PDF reporting process described in 40 CFR 
63.10031(f) is extended through December 31, 2023, to allow sufficient 
time for software development, programming, and testing. Until then, 
compliance with the emissions and operating limits will continue to be 
assessed based on the various PDF report submittals described in 40 CFR 
63.10031(f) and data from Hg, HCl, HF, and SO2 CEMS and 
sorbent trap monitoring systems, as reported through the ECMPS Client 
Tool. On and after January 1, 2024, compliance with the emissions and 
operating limits is assessed based on: (1) Quarterly compliance 
reports; (2) hourly data from all continuous monitoring systems (CMS) 
(including PM CEMS and PM CPMS) in XML format; (3) detailed reference 
method information for stack tests and CMS performance evaluations in 
XML format and PDF files; (4) Notifications of Compliance Status (if 
any) in PDF files; and (5) if applicable, supplementary data in PDF 
files for EGUs using paragraph 2 of the definition of startup in 40 CFR 
63.10042. The ECMPS Client Tool is required to submit all of these 
reports and notifications.
    (3) In order to properly close out the interim PDF reporting 
process, 40 CFR 63.10031(f)(6) states that PDF submittals are still 
accepted as necessary for the reports required under paragraph (f) 
introductory text, (f)(1), (2), or (4) if the deadlines for submitting 
those reports extend beyond December 31, 2023. As an example, the last 
semiannual compliance report under the interim PDF reporting process 
covers the period from July 1, 2023, through December 31, 2023; the 
deadline for submitting this report is January 30, 2024, and the report 
is submitted using the interim PDF reporting process.
    (4) Revised paragraph (f)(2) of 40 CFR 63.10031 expands the 
quarterly reporting of 30- or 90-boiler operating day rolling average 
emission rates to include units monitoring Hg, HCl, HF, and/or 
SO2 emissions, and units using emissions averaging. This 
change is consistent with 40 CFR 63.10031(f)(2) of the current rule, 
which requires quarterly reporting of 30-boiler operating day rolling 
averages for EGUs using PM CEMS, PM CPMS, and approved HAP metals CEMS. 
Therefore, starting with the first quarter of 2024, the 30- or 90-
boiler operating day rolling averages (or, if applicable, rolling 
weighted average emission rates (WAERs) if emissions averaging is used) 
are reported quarterly in XML format for all parameters (including Hg, 
HF, HCl, and SO2). However, instead of providing these 
rolling averages in separate, stand-alone reports, they are 
incorporated into the quarterly compliance reports required under 40 
CFR 63.10031(g) (see section IV.A.(9) of this preamble, below).
    (5) Revised paragraphs (a)(1), (2), and (5) of 40 CFR 63.10031 
clarify the electronic reporting requirements for the Hg, HCl, HF, 
SO2, and additional CMS. Specifically:
    (i) Paragraph (a)(1) requires the electronic reporting requirements 
of appendix A to be met if Hg CEMS or sorbent trap monitoring systems 
are used.
    (ii) Paragraph (a)(2) requires the electronic reporting 
requirements of appendix B to be met, with one important qualification, 
if HCl or HF monitoring systems are used. Until December 31, 2023, if 
PS 18 in part 60, appendix B is used to certify an HCl monitor and 
Procedure 6 in part 60, appendix F is used for on-going QA of the 
monitor, EGU owners or operators will temporarily report only data that 
the existing programming of ECMPS is able to accommodate, i.e., hourly 
HCl emissions data and the results of daily calibration drift tests and 
RATAs; records are to be kept of all of the other required 
certification and QA tests and supporting data. The reason for this 
temporary, limited reporting is that PS 18 and Procedure 6 were not 
published until July 7, 2015; therefore, it was not possible to specify 
recordkeeping and reporting requirements for them in the original 
version of appendix B. Now that PS 18 and Procedure 6 have been 
finalized, this rule adds the necessary recordkeeping and reporting 
requirements, and the interim reporting for HCl will be discontinued as 
of January 1, 2024 (for further discussion, see section IV.C of this 
preamble).
    (iii) Paragraph (a)(5) clarifies the electronic reporting 
requirements for the SO2 CEMS and the additional monitoring 
systems under MATS. Sources currently reporting SO2 mass 
emissions under the Acid Rain Program or Cross-State Air Pollution Rule 
already meet these requirements, except for paragraphs (a)(5)(iii)(C) 
and (E), which require, respectively, quarterly reporting of an hourly 
SO2 emission rate data stream in units of the applicable 
MATS standard (i.e., pounds per British thermal units (lb/MMBtu) or 
pounds per megawatt hours (lb/MWh)) and certification statements from 
the responsible official. Separate certification statements are 
required for the 40 CFR part 75 programs and MATS. (Note: For 
consistency with the changes described in items (i) through (iii), 
immediately above, 40 CFR 63.10031(f)(3) is removed and reserved).
    (6) Paragraphs (b)(1) and (2) of 40 CFR 63.10031 are amended to 
recognize that some EGUs may have received extensions of their 
compliance date under 40 CFR 63.6(i)(4). References to

[[Page 55748]]

postmark dates for submittal of semiannual compliance reports 
paragraphs are removed from paragraphs (b)(2) and (4); these reports 
currently are, and continue to be, submitted electronically through 
ECMPS as PDF files, until they are superseded by quarterly compliance 
reports, starting in the first quarter of 2024.
    (7) The provision in 40 CFR 63.10031(b)(5), which allows affected 
EGU owners or operators to follow alternate submission schedules for 
semiannual compliance reports are discontinued when the interim PDF 
reporting period ends. When that interim PDF reporting period ends, the 
uniform submission schedule described in 40 CFR 63.10031(b)(1) through 
(4) is required for all affected EGUs, so that compliance with this 
reporting requirement can easily be tracked.
    (8) New 40 CFR 63.10031(b)(6) will require EGU owners or operators 
to discontinue submission of semiannual compliance reports when the 
interim PDF reporting period ends. The final semiannual compliance 
report covers the period from July 1, 2023, through December 31, 2023.
    (9) EGU owners or operators submit quarterly compliance reports in 
lieu of the semiannual compliance reports, starting with reports 
covering the first quarter of 2024 (see 40 CFR 63.10031(g)). The 
quarterly compliance reports retain many features of the semiannual 
reports and consolidate them with other reports that were originally 
required to be submitted separately on different schedules. These 
compliance reports will be due within 60 days after the end of each 
calendar quarter, which allows sufficient time to receive the results 
of stack tests (particularly PM, HCl, and HF tests) performed at or 
near the end of a calendar quarter. Each quarterly compliance report 
includes the applicable data elements listed in sections 2 through 13 
of appendix E.
    The owner or operator's MATS compliance strategy determines which 
of the data elements in sections 2-13 of appendix E are included in the 
quarterly compliance reports. If continuous emission monitoring were 
used to demonstrate compliance on a 30- or 90-boiler operating day 
rolling average basis, the quarterly compliance reports include all of 
the 30- or 90-day averages calculated during the quarter. If emissions 
averaging were used, EGU owners or operators report all of the 30- or 
90-group boiler operating day WAERs calculated during the quarter. If 
periodic stack testing for compliance were performed (including Hg LEE 
tests and PM tests to set operating limits for PM CPMS), the EGU owner 
or operator reports a summary of each test completed during the 
calendar quarter and indicate whether the test has a special purpose 
(i.e., if it were to be used to establish LEE status or for emissions 
averaging).
    The quarterly compliance reports retain and incorporate the 
following features of the semiannual compliance reports: (1) Boiler 
tune-up dates; (2) monthly fuel usage data; (3) process and control 
equipment malfunction information; (4) reporting of deviations; and (5) 
emergency bypass information, for certain EGUs that qualify for and 
elect to use the LEE compliance option for Hg. However, for EGU owners 
or operators who elect to (or are required to) use CMS to demonstrate 
compliance, these quarterly reports, to some extent, move away from 
traditional ``exception only'' reporting. Currently, reporting of the 
excess emissions and monitor downtime information described in 40 CFR 
63.10(e)(3)(v) and (vi) in PDF files has been required as part of the 
semiannual compliance reports. That information includes, among other 
things, identification of excess emissions periods, identification of 
periods when the monitoring system was inoperative or out of control, 
the reasons for the excess emission and monitor downtime periods, 
corrective actions or preventative measures taken, description of 
repairs or adjustments to inoperative or out-of-control CMS, the total 
amount of source operating time in the reporting period, and the excess 
emissions and monitor downtime, expressed as percentages of the source 
operating time. As explained above, rather than this traditional 
exception-only reporting, these amendments require all of the 30- (or 
90-) boiler operating day rolling averages or WAERs for all parameters 
to be included in the quarterly compliance reports. In addition, the 
following elements of the excess emissions summary, with slight 
modifications, are included in the quarterly compliance reports: (1) 
The total number of source operating hours in the quarter and (2) the 
total number of hours of monitoring system downtime for various causes 
(known and unknown).
    As previously noted, the requirement to report deviations is 
retained in the quarterly compliance reports. Specifically, the 
revisions to 40 CFR 63.10031(d) require the applicable data elements in 
section 13 of appendix E to be reported, which include the nature of 
the deviation (section 13.2), a description of the deviation (section 
13.3), and any corrective actions taken (section 13.4). Section 13.3 
further specifies the minimum amount of information reported in the 
description of certain deviations or monitoring downtime (i.e., 
unmonitored bypass stack usage, emissions or operating limit 
exceedances, monitoring system outages, and missed or late performance 
stack tests).
    We believe that consolidating information in quarterly compliance 
reports, as described above, rather than requiring separate submittals 
of 30- (or 90-) boiler operating day rolling average reports, excess 
emissions reports, and semiannual compliance reports that come in 
separately at different times during the year, greatly simplifies 
reporting and makes it easier for inspectors and auditors to assess 
compliance with the standards. Also, quarterly, as opposed to 
semiannual, reporting is advantageous because it shortens significantly 
the interval between the time that deviation or exceedance reporting on 
a term longer than quarterly occurs. Draft reporting instructions for 
the quarterly compliance reports are provided in the rule docket. In 
response to comments received, these instructions have been modified 
from a previous draft version.
    (10) A new paragraph (c)(10) is added to section 63.10031 and 
requires malfunction information to be included in the semiannual 
compliance reports. This is not a new requirement; it was previously 
found in paragraph (g). However, as explained above, revised paragraph 
(g) requires quarterly compliance reports to be submitted, starting in 
2024. Therefore, to avoid losing the requirement to report malfunction 
information in the semiannual compliance reports, the former paragraph 
(g) has been renamed as paragraph (c)(10) and is added to the list of 
information that must be included in the semiannual reports. The 
introductory text of paragraph (c) is also amended, to recognize the 
addition of paragraph (c)(10).
    (11) For consistency with the reporting requirements for the other 
CMS, the regulation does not require source owners or operators using 
PM CPMS to submit separate quarterly excess emission summary reports in 
addition to the quarterly compliance reports. After careful 
consideration of comments on the previous proposal, we are persuaded 
that sufficient information to assess compliance with the operating 
limits of a PM CPMS will be provided by: (1) The hourly PM CPMS 
response data reported in appendix D; (2) the quarterly compliance 
reports, which specify the operating limit of the PM CPMS, require

[[Page 55749]]

deviations from the operating limit and monitoring requirements to be 
reported, and include summarized results of the PM tests used to 
develop the operating limits; and (3) the applicable reference method 
data for the PM tests required to be reported under sections 17-30 of 
appendix E.
    Table 9 to 40 CFR part 63, subpart UUUUU is amended to reflect the 
transition away from exception-only reporting. The applicability of the 
recordkeeping and reporting requirements for excess emission and 
monitor downtime summary reporting in 40 CFR 63.7(c)(8), 63.10(c)(7), 
and 63.10(e)(3) ends on December 31, 2023, with the phase-out of the 
semiannual compliance reports.
    (12) One commenter on the previous proposal brought to light some 
inconsistencies in the rule; regarding the way in which periods of 
monitor downtime should be regarded and reported, i.e., whether or not 
they are reportable deviations. We thought the April proposal addressed 
this concern, but other commenters asked for clarification during the 
current comment period. As the Agency meant to exempt periods of 
routine QA or quality control (QC) and routine maintenance from 
deviation reporting but not from monitoring downtime reporting, 
language in 40 CFR 63.10010(h)(5), (i)(4), and (j)(4) has been 
clarified, along with the clarifications to 40 CFR 63.10020(b) and (d), 
40 CFR 63.10010(h)(6)(i) and (ii), (i)(5)(i) and (ii), and (j)(4)(i)(A) 
and (B) that were proposed in April. We also clarified the 
corresponding data elements in section 13 of Appendix E.
    In response to comments for clarification concerning reporting of 
QA test results, which the Agency maintains is mandatory for all CMS, 
the regulation has been amended at 40 CFR 63.10010 to remove the last 
sentence in paragraphs (h)(6)(i), (j)(4)(i)(A) and (B); to require the 
monitoring system performance evaluations of PM CPMS and HAP metals 
CEMS be reported in paragraphs (h)(7) and (j)(4)(ii), respectively; to 
require the QA/QC activities for PM CPMS and HAP metals CEMS be 
reported quarterly in PDF files in 40 CFR 63.10031(k); and to cross-
reference the appropriate sections of appendix C, regarding the 
certification, operation, maintenance, on-going QA, recordkeeping, and 
reporting requirements for PM CEMS in 40 CFR 63.10010(i).
    (13) In all cases in which periodic stack tests (including Hg LEE 
tests and PM tests that are used to develop PM CPMS operating limits) 
are performed to demonstrate compliance, the rule retains the 
requirement for the EGU owner or operator to provide the applicable 
reference method data in appendix E (i.e., sections 17 et. seq.) for 
each stack test that is performed to demonstrate compliance. Each of 
these submittals is required to accompany the quarterly compliance 
report that covers the calendar quarter in which the test was 
completed. For PM tests that are used to develop PM CPMS operating 
limits, EGU owners or operators will be required to include the 
information in 40 CFR 63.10023(b)(2)(vi) as part of the Test Comment 
data element found in section 17.25 of appendix E.
    (14) The applicable reference method data in sections 17 through 30 
of appendix E will be required to be provided in XML format, starting 
with tests completed on or after January 1, 2024, for each RATA of an 
Hg, SO2, HCl, or HF monitoring system, and for each RRA, 
RCA, or correlation test of a PM CEMS. The information in section 31 of 
appendix E is provided in a PDF file for each test. The appendix E 
information is submitted concurrently with the summarized electronic 
test results submitted to ECMPS under appendix A, B, or C, or 40 CFR 
part 75 (for SO2 RATAs).
    (15) The ECMPS Client Tool is also used to make the following 
submittals in PDF files:
    (i) a detailed report of the current, active PS 11 correlation 
test, if the EGU owner or operator is using a certified PM CEMS to 
demonstrate compliance. For correlation tests completed prior to 
November 9, 2020, the report is due no later than 60 days after that 
date. For correlation tests completed on or after November 9, 2020, but 
prior to January 1, 2024, the report is due within 60 days after the 
date on which the test is completed. (Note: For correlations completed 
on and after January 1, 2024, in lieu of a PDF report, the test results 
are submitted electronically according to section 7.2.4 of appendix C, 
together with the applicable reference method data required under 
sections 17 through 31 of appendix E);
    (ii) any initial Notification of Compliance Status issued on or 
after January 1, 2024; and
    (iii) the information specified in 40 CFR 63.10031(c)(5)(ii) and 40 
CFR 63.10020(e) for startup and shutdown incidents, if an EGU owner or 
operator is relying on paragraph (2) of the definition of startup in 40 
CFR 63.10042. Starting with a report covering the first calendar 
quarter of 2024, this information is submitted along with the quarterly 
compliance report. Note that 40 CFR 63.10031(c)(5)(iii) through (v), 
which require the semiannual compliance reports to include the hourly 
CEMS and operating parameter data recorded during startup and shutdown 
events have not been carried over to this PDF report because this 
information is duplicative of the hourly data reported electronically 
in the quarterly emissions reports. Startup and shutdown hours are 
flagged in the emissions reports and are identifiable for auditing 
purposes.
    (16) To accommodate the required PDF reports, the applicable data 
elements in 40 CFR 63.10031(f)(6)(i) through (xii) are entered into the 
ECMPS Client Tool at the time of submission of each PDF file. Note that 
the amendment to data element (xii) replaces the word ``conducted'' 
with the word ``completed.''
    (17) Although the ECMPS Client Tool is used to submit the required 
reports and notifications described in revised 40 CFR 63.10031 and 
Table 8, ECMPS does not evaluate any of the PDF submittals or any of 
the XML-formatted reference method data from sections 17 through 31 of 
appendix E. Instead, these reports and notifications are transmitted 
directly through the EPA's Central Data Exchange using CEDRI unaltered. 
ECMPS does, however, perform electronic checking of the hourly PM CEMS 
data and the summarized RATAs, PM CEMS correlation tests, RRAs, and 
RCAs that are submitted in XML format, in a manner that is consistent 
with the way that certification and QA test results are evaluated under 
the Acid Rain and Cross-State Air Pollution Rule programs. ECMPS uses 
the results of these evaluations to assess the quality-assured status 
of the Hg, HCl, HF, SO2, or PM emissions data. In addition, 
ECMPS performs basic checks of the information in the quarterly 
compliance reports, e.g., checking for completeness and proper 
formatting, but leaves compliance assessment to those who review the 
reports. The EPA intends for all of these various data submissions to 
work together in a complementary fashion to enable meaningful 
compliance determinations. It is essential that any problems with the 
data identified by the reviewers are communicated to all involved and 
resolved appropriately. For example, if, for a particular Hg RATA, a 
review of the reference method data shows that the method was not done 
properly, the RATA would be invalidated. If, at the time of this 
discovery, the deadline for performing the RATA has passed and the 
allowable grace period has also expired, this improper RATA results in 
invalidation of hourly emissions data, from the expiration of the grace 
period until a valid RATA is performed and

[[Page 55750]]

passed. Consequently, resubmission of quarterly emissions reports, 
recalculation of 30-day compliance averages, and resubmission of 
quarterly compliance reports may become necessary.

B. Revisions to Appendix A

    Based on comments received, six sections of appendix A, i.e., 
sections 5.1.1, 7.1.1.2.1, 7.1.3.3, 7.1.4.3, 7.1.8.2 and 7.2.3.1 are 
amended and described, here. The requirement in section 5.1.1 regarding 
required QA testing is clarified to allow daily calibrations to be 
performed offline and to specify that ongoing QA testing other than 
RATAs can be performed at no particular load levels.
    The requirement in section 7.1.1.2.1 for electronic reporting is 
expanded to include emission controls. As part of the re-examination of 
the list of data elements that compose a complete test report, 
suggested by commenters, this data element was found to be missing in 
this section. The requirement in sections 7.1.3.3, 7.1.4.3, and 7.1.8.2 
to report Hg concentrations and emission rates to three significant 
figures is revised so that Hg concentrations in micrograms per standard 
cubic meter ([micro]g/scm) and Hg emission rates in pounds per trillion 
British Thermal Units or pounds per gigawatt-hour are reported with one 
leading non-zero digit and one decimal place, in scientific notation. 
Conventional rounding is used, i.e., if the digit immediately following 
the first decimal place is 5 or greater, the digit in the first decimal 
place is rounded upward (increased by one); if the digit immediately 
following the first decimal place is 4 or less, the digit in the first 
decimal place remains unchanged.
    The requirement in section 7.2.3.1 to submit monitoring plan 
information at least 21 days before the applicable compliance date in 
40 CFR 63.9984 is revised. For new EGUs or EGUs that install Hg 
monitoring systems in order to switch from another MATS-compliant 
methodology to Hg monitoring, the monitoring plan information is 
submitted at least 21 days prior to the date on which certification 
testing begins. However, for EGUs implementing Hg monitoring with a 
previously-certified Hg monitoring system, the monitoring plan may be 
submitted prior to or concurrent with the first quarterly emissions 
report--provided that the monitoring plan is in place when the first 
emissions report is submitted so that the ECMPS Client Tool is able to 
evaluate the data.

C. Revisions to Appendix B

    For affected source owners or operators desiring to continuously 
monitor HCl emissions, the original version of appendix B required the 
monitoring system to be certified according to PS 15 in appendix B to 
40 CFR part 60. However, PS 15 applies only to Fourier Transform 
Infrared (FTIR) Spectroscopy monitoring systems; therefore, the use of 
other viable HCl monitoring technologies was excluded. In view of this, 
the EPA regarded the requirement to use PS 15 exclusively as a 
temporary measure, until a technology-neutral PS for HCl monitors could 
be developed and published. In section 3.1 of appendix B, the Agency 
stated its intention to publish such a PS in the near future together 
with appropriate on-going QA requirements and to amend appendix B to 
accommodate their use. This additional PS, (PS 18 in 40 CFR part 60, 
appendix B), and the on-going QA test requirements (Procedure 6 in 40 
CFR part 60, appendix F) were published on July 7, 2015 (80 FR 38628, 
July 7, 2015).
    Now that technology-neutral certification and QA test requirements 
for HCl monitors are promulgated, EGU owners or operators may use any 
viable HCl monitoring technology that can meet PS 18. However, in order 
for ECMPS to accommodate all of the tests required under PS 18 and 
Procedure 6, additional time must be allotted for software development. 
In view of this, 40 CFR 63.10031(a)(2) is revised, as previously noted, 
to require only information that is compatible with the existing 
programming of ECMPS to be reported electronically through December 31, 
2023; this includes hourly HCl emissions data and the results of daily 
calibration drift tests and RATAs. In the interim, EGU owners or 
operators are required to keep records of all of the other 
certification and QA tests, which would be reported starting in 2024.
    The title to section 2.3 of appendix B is revised by deleting the 
reference to FTIR-only monitoring systems. In addition, the 
recordkeeping and reporting sections of appendix B (i.e., sections 10 
and 11) are amended. Based on comments received, sections 10.1.3.3 and 
10.1.7.2, HCl and HF concentrations ([micro]g/scm) and emission rates 
(lb/MMBtu or lb/MWh) are reported with one leading non-zero digit and 
one decimal place, in scientific notation, rather than reporting the 
concentrations and rates to three significant figures. Conventional 
rounding is used, i.e., if the digit immediately following the first 
decimal place is 5 or greater, the digit in the first decimal place is 
rounded upward (increased by one); if the digit immediately following 
the first decimal place is 4 or less, the digit in the first decimal 
place remains unchanged. Sections 10 and 11 also specify the data 
elements that are recorded and reported for each of the tests required 
by PS 18 and Procedure 6. The revisions make a clear distinction 
between the tests required for FTIR monitors that are following PS 15 
and the test requirements of PS 18 and Procedure 6. Some of the tests 
in PS 18 and Procedure 6 are similar to tests for which ECMPS 
programming exists. For example, the ``measurement error test'' 
required for initial certification of the HCl monitor is structurally 
the same as a 40 CFR part 75 linearity check. Other tests have no 
counterpart in 40 CFR part 75 and require special software development 
and reporting instructions. Note that electronic reporting of these 
tests through ECMPS would have been required if PS 18 and Procedure 6 
had been in place when the original MATS rule was published. In view of 
this, for source owners or operators electing to use HCl CEMS, the 
amendments to section 11 of appendix B introduce no unnecessary 
reporting burden. The results of certification and on-going QA tests 
are reported electronically for all CEMS required under this rule in 
order for ECMPS to assess the quality-assured status of the emissions 
data. The Agency also notes that not all of the tests described in 
section 11 of appendix B are required for all HCl monitors. For 
example, some of the tests (i.e., beam intensity, temperature, and 
pressure verifications) are specific to integrated path-CEMS, and 
Procedure 6 would offer a choice among three different types of audits 
(i.e., cylinder gas audits, relative accuracy audits, or dynamic 
spiking audits) for the required quarterly QA tests. In addition, based 
on comments received, the reporting requirements for the interference 
check (which is not necessarily performed on each individual analyzer) 
are reduced.
    For each RATA of HCl CEMS that are completed on and after January 
1, 2024, the applicable reference method data in sections 17 through 31 
of appendix E are submitted along with the electronic summary of 
results required under section 11 of appendix B. To the extent 
practicable, these data are submitted prior to or concurrent with the 
relevant quarterly electronic emissions report. However, as previously 
noted, this may not always be possible, particularly when the RATA is 
done near the end of a calendar quarter. The EPA test Methods 26 and 
26A, unlike instrumental test methods, require

[[Page 55751]]

laboratory analyses of the collected samples and cannot provide test 
results while the test team is on-site. In view of this, section 11.4 
of appendix B allows the test results to be submitted up to 60 days 
after the test completion date. ``Provisional'' status may be claimed 
for the emissions data affected by the test, starting from the date and 
hour in which the test is completed, and continuing until the date and 
hour in which the test results are submitted. If the test is 
successful, the status of the data in that time period change from 
provisional to quality-assured, and no further action is required. 
However, if the test is unsuccessful, the provisional data are 
invalidated, and resubmission of the affected emissions report(s) is 
required.
    Because a technology-neutral PS for HCl CEMS was not available 
prior to April 16, 2015 (which was the compliance date for many of the 
existing EGUs), EGU owners or operators interested in monitoring HCl 
either had to use an FTIR system and follow PS 15 or implement another 
compliance option (e.g., quarterly emission testing) while awaiting 
publication of PS 18 and Procedure 6. In light of this, section 11.5.1 
of appendix B now clarifies when electronic reporting of hourly HCl 
emissions data begins. There are two possibilities. In the first case, 
the monitor is used for the initial compliance demonstration. This 
could either apply to a certified FTIR monitor following PS 15 or to a 
certified monitor following PS 18, if the owner or operator of the EGU 
received an extension of the compliance date. In this case, EGU owners 
or operators begin reporting hourly HCl emissions through ECMPS with 
the first operating hour of the initial compliance demonstration. In 
the second case, another option, such as stack testing, is used for the 
initial compliance demonstration and continuous monitoring is 
implemented at a later time. In that case, EGU owners or operators 
begin reporting hourly HCl emissions reporting through ECMPS with the 
first operating hour after successfully completing all required 
certification tests of the CEMS. In either case, the first quarterly 
emissions report submittal is for the calendar quarter in which 
emissions reporting begins.
    The requirement in section 11.3.1 to submit monitoring plan 
information at least 21 days before the applicable compliance date in 
40 CFR 63.9984 is revised. For new units or units that install HCl and/
or HF monitoring systems in order to switch from another MATS-compliant 
methodology to HCl and/or HF monitoring, the monitoring plan 
information must be submitted at least 21 days prior to the date on 
which certification testing begins. However, for units implementing HCl 
and/or HF monitoring with a previously-certified monitoring system, the 
monitoring plan may be submitted prior to or concurrent with the first 
quarterly emissions report.
    Section 11.4.13 clarifies the reporting requirements for stack gas 
flow rate, moisture, and diluent gas monitoring systems that are used 
for certification, recertification, diagnostic, and QA tests are from 
section 10.1.8.2 of this appendix; such systems are also certified and 
quality-assured according to 40 CFR part 75 of this chapter.

D. Addition of Appendix C

    A new appendix, i.e., appendix C, is added to subpart UUUUU of 40 
CFR part 63. Appendix C sets forth the continuous monitoring and 
reporting requirements for filterable PM. Appendix C is structurally 
similar to appendices A and B, but there is one notable difference. 
Appendix C includes provisions for installation and certification of 
the PM CEMS, and for on-going QA of the data from the CEMS. The 
monitoring system is certified according to PS 11 in 40 CFR part 60, 
appendix B, and for the on-going QA tests, Procedure 2 to 40 CFR part 
60, appendix F is being required.
    After consideration of comments received, the EPA has concluded 
that all PM concentrations will be reported in units of measure that 
are consistent with the PM CEMS correlation. For example, if the PM 
CEMS measures in units of milligrams per actual cubic meter (mg/acm) 
and the concentrations used to derive the correlation curve are in 
those same units, then the hourly PM concentrations are recorded and 
reported in mg/acm. Section 7.1.9.5 of appendix C also requires the 
reference method readings and the PM CEMS responses obtained in the 
RRAs and RCAs to be reported in the same units of measure as the PM 
CEMS correlation curve.
    Sections 7.1.3.3 and 7.1.7.2 require PM concentrations and emission 
rates (lb/MMBtu or lb/MWh) to be reported with one leading non-zero 
digit and one decimal place, in scientific notation, rather than 
reporting the concentrations and rates to three significant figures. 
Conventional rounding is used, i.e., if the digit immediately following 
the first decimal place is 5 or greater, the digit in the first decimal 
place is rounded upward (increased by one); if the digit immediately 
following the first decimal place is 4 or less, the digit in the first 
decimal place remains unchanged.
    The frequencies for the on-going QA tests and the rules for data 
validation are presented in section 5 of appendix C. In response to 
numerous requests from commenters, the frequency and data validation 
rules for the RCAs and RRAs are similar, but not identical to, 
provisions of 40 CFR part 75. The frequency of these tests follows the 
familiar calendar quarter and grace period reporting plan. An RRA is 
required once every 4 calendar quarters and an RCA is required once 
every 12 calendar quarters. A grace period is provided (i.e., 720 
operating hours or 1 calendar quarter, whichever comes first), to cover 
cases where circumstances beyond the control of the owner or operator 
prevent the required test from being completed on schedule. In 
addition, as explained in detail below, section 7.2.4 of appendix C 
allows the use of provisional data for up to 60 days after completion 
of an RRA, RCA, or PM CEMS correlation test.
    The procedures for calculating the PM emission rates in units of 
the emission standard are found in section 6. These calculation methods 
are basically the same as those used for Hg monitoring systems and for 
HCl and HF CEMS in appendices A and B. The recordkeeping and reporting 
requirements are found in section 7. Section 7.1 requires monitoring 
plan records and hourly records of operating parameters, PM 
concentration, diluent gas concentration, stack gas flow rate and 
moisture content, and PM emission rates are kept. Sections 7.2.3 and 
7.2.4, respectively, require monitoring plan information and the 
results of certification, recertification, and QA tests are reported 
electronically. For consistency with these revisions to appendices A 
and B, section 7.2.3.1 specifies that for new units or units installing 
PM CEMS in order to switch from another MATS-compliant methodology to 
PM monitoring, the electronic monitoring plan information is submitted 
at least 21 days prior to the commencement of certification testing. 
However, for EGUs with previously-certified PM CEMS that elect to 
implement PM monitoring, the monitoring plan information may be 
submitted prior to or concurrent with the first quarterly emissions 
report. Section 7.2.5 requires quarterly electronic emissions reports 
are submitted within 30 days after the end of each calendar quarter. 
All electronic reports are submitted using the ECMPS Client Tool. 
However, for EGUs that began using the PM CEMS compliance option prior 
to January 1, 2024, electronic reporting of monitoring plan 
information, certification and on-going QA test results, hourly PM 
emissions

[[Page 55752]]

data, and the applicable reference method data in appendix E does not 
begin until January 1, 2024, to allow time for software development and 
beta testing. Until then, records of the required information and tests 
are kept. For EGUs that certify and begin using PM CEMS on or after 
January 1, 2024, reporting of hourly PM emissions data begin with the 
first operating hour after successful completion of the initial PM CEMS 
correlation test.
    For PM CEMS correlations, RRAs, and RCAs completed on and after 
January 1, 2024, the applicable reference method data in sections 17 
through 31 of appendix E are submitted along with the electronic test 
summary required under section 7.2.4 of appendix C. To the extent 
practicable, the electronic test results and the appendix E reference 
method data are submitted prior to or concurrent with the relevant 
quarterly electronic emissions report. However, the EPA recognizes that 
this is not always possible, particularly when an RRA or RCA is done 
near the end of a calendar quarter. The EPA test Methods 5 and 5D, 
unlike instrumental test methods, require laboratory analyses of the 
collected samples and generally cannot provide test results while the 
test team is on-site. In view of this, section 7.2.4 of appendix C 
allows the test results to be submitted up to 60 days after the test 
completion date. ``Provisional'' status may be claimed for the 
emissions data affected by the test, starting from the date and hour in 
which the test is completed, and continuing until the date and hour in 
which the test results are submitted. If the test is successful, the 
status of the data in that time period changes from provisional to 
quality-assured, and no further action is required. However, if the 
test is unsuccessful, the provisional data would be invalidated, and 
resubmission of the affected emission report(s) is required.

E. Addition of Appendix D

    A new appendix, i.e., appendix D, is added to subpart UUUUU of 40 
CFR part 63. Appendix D sets forth the monitoring and reporting 
requirements for EGU owners or operators who elect to use a PM CPMS to 
demonstrate continuous compliance. Structurally, appendix D is similar 
to appendices A, B, and C. However, the criteria for system design and 
performance, the procedures for determining operating limits, data 
reduction, and compliance assessment, and certain recordkeeping 
requirements are not detailed in the appendix; rather, the applicable 
sections of the MATS rule are cross-referenced (see sections 2.1 
through 2.4, 3.1 introductory text, and section 3.1.1.1 of the 
appendix).
    Section 3.1.1.2 requires the ECMPS Client Tool to be used to create 
and maintain an electronic monitoring plan. The PM CPMS is defined as a 
monitoring system with a unique system ID number. The monitoring plan 
also includes the current operating limit (with units of measure), the 
make, model, and serial number of the PM CPMS, the analytical principle 
of the monitoring system, and monitor span and range information.
    The rule requires operating parameter records for each hour of 
operation of the affected EGUs, including the date and hour, the EGU or 
stack operating time, and a flag to identify exempt startup and 
shutdown hours. Hourly average PM CPMS output values are reported for 
each hour in which a valid value of the output parameter is obtained, 
in units of milliamps, PM concentration, or other units of measure, 
including the instrument's digital signal output equivalent. A special 
code is required to indicate operating hours in which valid data are 
not obtained. The percent monitor data availability is calculated in 
the manner established for SO2, carbon dioxide 
(CO2), oxygen (O2), or moisture monitoring 
systems in 40 CFR 75.32.
    Sections 3.2.2 and 3.2.3, respectively, require notifications 
(provided in accordance with 40 CFR 63.10030) and electronic monitoring 
plan submittals at specified times. For EGUs using the PM CPMS 
compliance option prior to January 1, 2024, the electronic monitoring 
plan information is submitted prior to or concurrent with the first 
quarterly report. For EGUs switching to the PM CPMS compliance option 
on or after January 1, 2024, the electronic monitoring plan is 
submitted no later than 21 days prior to the PM test that establishes 
the initial operating limit. Section 3.2.4 requires the electronic 
quarterly reports to be submitted within 30 days after the end of each 
calendar quarter. Reporting of hourly responses from the PM CPMS begins 
either with the first operating hour of 2024 or the first operating 
hour after completion of the stack test that establishes the initial 
operating limit, whichever is later. Each quarterly report includes a 
compliance certification with a statement by a responsible official 
that to the best of his or her knowledge, the report is true, accurate, 
and complete.
    In addition to the electronic quarterly reports, the rule requires 
reporting of deviations from the operating limit in the quarterly 
compliance reports required under 40 CFR 63.10031(g). Further, section 
3.2.5 of appendix D requires the results of each performance stack test 
for PM that is used to establish an operating limit are reported 
electronically in the relevant quarterly compliance report. For PM 
tests completed on and after January 1, 2024, the applicable appendix E 
reference method data are also submitted along with the relevant 
quarterly compliance report.

F. Addition of Appendix E

    A new appendix, i.e., appendix E, is added to subpart UUUUU of 40 
CFR part 63. Sections 2 through 13 of appendix E list the data elements 
that are reported in XML format in the quarterly compliance reports 
required under 40 CFR 63.10031(g), starting with reports covering the 
first quarter of 2024.
    The MATS compliance strategy (e.g., whether the EGU owner or 
operator elects to perform periodic stack testing, continuous 
monitoring, or to use emissions averaging) and the events that occur 
during each calendar quarter determine which data elements in sections 
2 through 13 are included in the quarterly compliance reports. As noted 
in section V.A.(9) of this preamble, updated reporting instructions for 
these compliance reports are found in the rule docket.
    For reasons stated in the previous proposal's Response to Comments 
document (which is available in the rule docket \3\), the basic 
provisions of sections 14 through 21 of appendix E, requiring details 
of the reference methods used for performance stack tests and CMS 
performance evaluations are reported in XML format are retained. The 
rule also retains the requirement in section 22 of appendix E to 
provide reference method test information that is incompatible with 
electronic reporting as PDF files, although it has been renumbered as 
section 31 and modified to include a cross-reference to 40 CFR 63.7(g), 
which describes the contents of a performance test report. The 
applicable reference method information in appendix E is provided for 
each stack test; each RATA of a Hg, HCl, HF, or SO2 
monitoring system; and each RRA, RCA, or correlation test of a PM CEMS 
that is completed on and after January 1, 2024.
---------------------------------------------------------------------------

    \3\ See EPA-HQ-OAR-2018-0794 at https://www.regulations.gov/.
---------------------------------------------------------------------------

    To address concerns raised by the commenters about portions of the 
2016 proposed rule \4\ (the previous proposal), specifically, the 
reporting requirements in sections 17 through 21 of proposed appendix 
E, the data element lists are

[[Page 55753]]

revised and reformatted to correspond to the compliance options 
described in section 16 of appendix E. Explicitly, sections 17 through 
30 replace previously proposed sections 17 through 21. Commenters 
pointed out, and the Agency concurs, that some of the previously 
proposed data elements are either unnecessary, inapplicable to MATS, or 
duplicative of information in other MATS reports; these elements have 
been removed from the lists and include:
---------------------------------------------------------------------------

    \4\ As mentioned in footnote 1, see 81 FR 67062, September 29, 
2016.
---------------------------------------------------------------------------

     Previously proposed 7.1.3.3.1 of appendix C to this 
subpart;
     Previously proposed 7.1.3.3.2 of appendix C to this 
subpart;
     Previously proposed 7.1.3.3.3 of appendix C to this 
subpart;
     Previously proposed 7.1.3.4 of appendix C to this subpart;
     Previously proposed 10.4 of appendix E to this subpart;
     Previously proposed 10.5.1 of appendix E to this subpart;
     Previously proposed 10.5.2 of appendix E to this subpart;
     Previously proposed 10.5.7 of appendix E to this subpart;
     Previously proposed 17.28 of appendix E to this subpart;
     Previously proposed 17.30 of appendix E to this subpart;
     Previously proposed 17.37 of appendix E to this subpart;
     Previously proposed 18.21 of appendix E to this subpart;
     Previously proposed 19.29 of appendix E to this subpart;
     Previously proposed 20.4 of appendix E to this subpart;
     Previously proposed 20.15 of appendix E to this subpart;
     Previously proposed 20.17 of appendix E to this subpart;
     Previously proposed 20.21 of appendix E to this subpart;
     Previously proposed 20.25 of appendix E to this subpart;
     Previously proposed 20.30 of appendix E to this subpart;
     Previously proposed 20.36 of appendix E to this subpart;
     Previously proposed 20.37 of appendix E to this subpart;
     Previously proposed 20.41 of appendix E to this subpart;
     Previously proposed 20.42 of appendix E to this subpart;
     Previously proposed 20.44 of appendix E to this subpart;
     Previously proposed 20.46 of appendix E to this subpart;
     Previously proposed 20.52 of appendix E to this subpart;
     Previously proposed 21.14 of appendix E to this subpart; 
and
     Previously proposed 21.28 of appendix E to this subpart.
    Reporting instructions for sections 17 through 30 have been 
developed. These draft example instructions are included in the rule 
docket.
    The reorganized data element lists and corresponding instructions 
clarify which data elements are reported for each compliance option and 
explain how the data are reported. Several new data elements are in the 
lists, to enable the ECMPS Client Tool to be used, to enhance the 
quality of the data, and to facilitate compliance. As mentioned in VI.C 
of this preamble, this action is expected to reduce overall annual 
source burden. The Agency believes that the addition of these data 
elements is offset by the removal of others, the change to a consistent 
submission frequency, and the merger of separate electronic reporting 
systems into just one electronic reporting system such that overall 
annual source reporting burden is reduced by 11,000 hours. The new data 
elements to be reported are as follows:
     ``Part.'' The previous proposal would only have required 
the ``Subpart'' to be reported. To avoid any possible confusion with 
other EPA regulations, both the CFR part (63) and subpart (UUUUU) need 
to be included in the reports.
     ``APS Flags.'' For 3-level pre-test calibrations, system 
bias, and drift checks, instrumental EPA test Methods 3A and 6C require 
certain acceptance criteria to be met. For each of these tests, there 
is a main PS and an alternative specification. The main PS is expressed 
as a percentage of span, while the alternative specification is the 
absolute difference between a reference value and the measured value. 
In view of this, it is important to know which specification has been 
applied to ascertain whether the test was successful or not. Therefore, 
alternative performance specification (APS) flags are to be added for 
the pre- and post-test calibrations, bias checks, and drift checks. An 
APS flag of ``0'' indicates that the reported test result is based on 
the main PS, whereas an APS flag of ``1'' means that the reported 
result is based on the APS.
     ``Test Comment.'' This text field is added to allow the 
affected sources to provide additional, pertinent information about a 
particular test.
     ``Run Begin Date'' and ``Run End Date.'' These two data 
elements replace the previous proposed element, ``Run Date,'' to cover 
cases where a test run begins on one day and ends on another (e.g., if 
a run begins late at night and ends early the next morning).
     ``Converted Concentration and Units of Measure.'' These 
data elements apply to correlation tests and performance audits (RRAs 
and RCAs) of PM CEMS. The reference method used for these tests is EPA 
test Method 5 (or, if applicable, 5D). The PM concentrations obtained 
from EPA test Method 5 or 5D are expressed in units of grams per dry 
standard cubic meter (g/dscm). However, consistent with section 8.6 of 
PS 11, appendix C of MATS requires all PM concentrations to be reported 
in units of measure that are consistent with the PM CEMS correlation 
curve. Most PM CEMS measure concentration in units of milligrams per 
actual cubic meter (mg/acm); others may measure at a certain 
temperature (e.g., mg/acm at 160 degrees Celsius), and still others may 
measure on a dry basis. Therefore, in addition to reporting the EPA 
test Method 5 test results in units of g/dscm, the converted PM 
concentrations must be reported in units consistent with the PM CEMS 
correlation curve.
     ``Average Sampling Rate and Units of Measure.'' These data 
elements are specific to EPA test Method 30B. That EPA test Method 30B 
requires a post-test leak check of each sampling train. The leakage 
rate must not exceed 4 percent of the average sampling rate. Therefore, 
to assess compliance with this specification, both the leakage rate and 
the average sampling rate must be reported. The previous proposed rule 
only required the leakage rate to be reported.
     ``Control Device Code.'' This data element refers to the 
control device code or control technology National Emission Inventory 
code associated with the EGU (or group of EGUs sharing a common stack). 
Providing this data element helps in EGU categorization and emission 
factor development.
     ``Corresponding Reference Method(s), if applicable.'' This 
data element allows pollutant reference method run data to be 
associated with concurrent measurements of the stack gas flow rate 
using EPA test Method 2, and/or CO2 or O2 
concentration using EPA test Method 3A, and/or stack gas moisture 
content using EPA test Method 4. Reporting this data element is 
necessary to ensure test methods were conducted properly so that 
emission rates can be calculated.
     ``Corresponding Reference Method(s) Run Number, if 
applicable.'' This data element provides the run number of concurrent 
reference method tests. The assigned run number of the EPA test Method 
1 through 4 or EPA test Method 3A tests conducted at the same time as a 
reference method test needs to be reported in order to ensure the

[[Page 55754]]

methods were conducted properly so that emission rates can be 
calculated.
     ``Pollutant Concentration Units of Measure.'' This data 
element provides the appropriate units of measure code for the 
pollutant or analyte concentration, and reporting it is necessary for 
comparison to the standard.
     ``Pollutant Emission Rate.'' This data element is the 
pollutant emission rate expressed in the units of the standard, and 
reporting it is necessary for comparison with the standard.
     ``Pollutant Emission Rate Units of Measure (in units of 
the standard).'' This data element is the units of the standard 
specified in Table 1 or 2 of this subpart. Reporting it is necessary 
for comparison to the standard.
     ``Process Parameter Units of Measure.'' This data element 
identifies the process rate parameter unit of measure: GWh/h, MWh/h, 
TBtu/h, or MMBTU/h, and reporting it is necessary to ensure accurate 
comparisons between runs and for emission factor development purposes.
     ``Total Pollutant Mass Trap A'' and ``Total Pollutant Mass 
Trap B.'' These data elements refer to the total Hg mass measured by 
Train A and Train B, respectively, in the appropriate units of measure. 
Reporting these values is necessary for QA purposes and for comparison 
with the standard.
     ``Method Detection Limit (MDL).'' This data element refers 
to the minimum amount of analyte that can be detected and reported. 
Reporting it is necessary for calculation checks and for emissions 
factor development purposes.
     ``Percent Spike Recovery.'' This data element refers to 
the spike recovery in percent, which is required to be reported by 
section 8.2.6.2 in EPA test Method 30B using Equation 30B-1.
     ``F-Factor (Fc).'' This data element expands 
the current F-factor choices to include the carbon F-Factor, which is 
based on the ratio of CO2 to heat content of fuel. Reporting 
it allows conversion from mass per volume to mass per heat input for 
those who choose to use emissions testing.
     ``Compliance Limit Basis (Heat Input or Electrical 
Output).'' This data element identifies the denominator of the 
compliance units selected for an existing EGU by its owner or operator. 
Reporting this decision is necessary for comparison of results with the 
standard.
     ``Heat Input or Electrical Output Unit of Measure.'' This 
data element specifies the denominator of the compliance unit that 
corresponds to the means of compliance selected for an existing EGU by 
its owner or operator. Reporting this unit is necessary for comparison 
of results with the standard and for emission factor development 
purposes.
     ``Pollutant Concentration.'' This data element expands the 
already-existing ``Emissions Concentration'' data element to include 
pollutants. Reporting this data element is necessary for comparison of 
results with the standard and for emission factor development purposes.
     ``Stack Gas Flow Rate--dscfm.'' This data element 
clarifies the already-existing ``Volumetric Flow Rate--scfm'' data 
element so that reporters will know to report their EGU's dry stack gas 
flow rate. Reporting this data element is necessary for calculation 
purposes.
    Several commenters \5\ on the September 29, 2016, proposed rule 
(i.e., the previous proposal) suggested that those proposed revisions 
included a significant amount of duplicative reporting, which should be 
eliminated. In response to the concerns expressed by the commenters, 
the Agency examined the XML data element lists twice--once in 2016 and 
recently after closure of the current comment period--for stack tests 
and CMS performance evaluations, in order to identify duplicative 
reporting and eliminate it where possible. The following evaluations 
were made:
---------------------------------------------------------------------------

    \5\ Commenters 20612, 20597, and 20609 on Docket ID No. EPA-HQ-
OAR-2009-0234.
---------------------------------------------------------------------------

    First, the data elements in sections 2 through 13 of appendix E 
(for the quarterly compliance reports) were compared against the data 
elements in sections 17 through 30 of appendix E (corresponding to the 
detailed reference method data for stack tests and CMS performance 
evaluations). The two lists were found to have 20 data elements in 
common, but at least nine of these elements (i.e., Source ID (Sampling 
Location), Test Number, Run Number, Run Begin Date, and a few others) 
are to be included in both XML schemas to properly link the individual 
stack test summaries in the compliance report with the corresponding 
reference method data.
    Second, the data elements listed in the reporting sections of 
appendices A, B, and C of MATS, requiring the results of CMS 
performance evaluations (i.e., RATAs, RRAs, and RCAs) to be reported 
using the ECMPS Client Tool, were compared against the corresponding 
reference method data elements in sections 17 through 30 of appendix E. 
Only 12 data elements common to the appendix E and ECMPS Client Tool 
schemas were found. This is not surprising because appendices A, B, and 
C require only summarized results of CMS performance evaluations--
details of the Reference Method tests are not reported. Of the 12 data 
elements common to the appendix E and ECMPS lists, 10 of them are to be 
included in both schemas to properly link the CMS test summaries with 
the corresponding reference method data.
    In view of these two evaluations, the EPA concludes that most of 
the duplicative reporting found among the various data element lists is 
necessary to ensure that the results of stack tests and CMS performance 
evaluations summarized in the quarterly compliance reports and the QA 
test submittals to the ECMPS Client Tool can be matched with the 
corresponding reference method data. Further, the remainder of the 
duplicative reporting is minimal, rather than ``significant'' as 
asserted by some commenters. The Agency believes that it is best not to 
modify the data element lists to eliminate this small amount of 
duplicate reporting. Although the deadlines for submitting the 
quarterly compliance reports and the corresponding reference method 
data are the same (i.e., within 60 days after the end of the quarter), 
the two XML reports might not be submitted concurrently. So, if, for 
instance, the compliance report is submitted prior to the reference 
method data, and certain data elements are found only in the reference 
method report, a thorough assessment of compliance may not be possible 
until the reference method report is received. Similar considerations 
apply to the summarized CMS performance evaluations in the ECMPS Client 
Tool and the corresponding reference method data, if the two XML 
reports are not submitted concurrently.

V. Revisions to Other Rule Text

    The revisions to 40 CFR 63.10031 necessitate changes to other 
sections of the rule to ensure that the rule is internally consistent. 
Based on comments received, revisions were made to clarify certain 
reporting requirements, to rectify inadvertent omissions, and to 
correct inconsistencies. The affected rule sections are as follows:
    (a) The introductory text of paragraphs (a)(2), (b), and 
(h)(3)(iii) of 40 CFR 63.10005 is revised. The amendment to paragraph 
(a)(2) clarifies that Hg compliance may either be determined on either 
a 30- or 90-boiler operating day rolling average basis. For consistency 
with appendix E, revised paragraph (b) notes that when auxiliary stack 
gas flow rate or moisture data are needed to supplement a performance 
stack test conducted with an isokinetic

[[Page 55755]]

method such as EPA test Method 5 or EPA test Method 26A, separate EPA 
test Method 2 or EPA Method 4 tests are not needed to satisfy the 
requirements of 40 CFR 63.10007 and Table 5. Data from the isokinetic 
method may be used to determine the stack gas flow rate and moisture 
content. Revised section (h)(3)(iii) addresses a commenter's request 
for clarification on how to calculate a 30-day Hg LEE test average.
    (b) Section 40 CFR 63.10009 is amended as follows. The second and 
third sentences in paragraph (a)(2) are revised to clarify the types of 
data that may be used to determine WAERs. Data from Hg CEMS, sorbent 
trap monitoring systems, but not LEE tests, may be used for Hg 
emissions averaging. For other pollutants, both CEMS data and stack 
test data may be used. The last sentence of paragraph (a)(2) is amended 
to clarify that if any EGU in an averaging group operates on any of the 
days in a 30- or 90-group boiler operating day compliance period 
(regardless of how many or how few), the emissions data from that EGU 
on those days must be included in the weighted average. Since averaging 
of Hg emissions is permitted on a 30-group boiler operating day basis, 
Equations 2a and 2b in 40 CFR 63.10009 apply to Hg as well as other 
pollutants. Therefore, the words ``for pollutants other than Hg'' are 
removed from the introductory text of paragraph (b)(2), and in the 
nomenclature of Equation 2a, the words ``or sorbent trap monitoring'' 
are added after the words ``unit i's CEMS'' in the definition of the 
term ``Heri.'' Finally, for completeness, Equations 3a and 
3b are amended by removing the terms that pertain to quarterly stack 
testing. Equations 3a and 3b apply only to the 90-group boiler 
operating day Hg WAER limit for coal-fired units. Coal-fired EGUs do 
not have the option to use quarterly stack testing to demonstrate 
compliance; if a coal unit does not qualify as a LEE, Hg emissions must 
be continuously monitored.
    (c) As explained in section IV.A(11) above, paragraphs (h)(6) and 
(7), (i), (j)(4)(i), and (j)(4)(ii) of 40 CFR 63.10010 are revised to 
resolve inconsistencies in the text.
    (d) Section 40 CFR 63.10011(e) is revised to require Notifications 
of Compliance Status for initial compliance demonstrations include the 
information specified in 40 CFR 63.10030(e), and are submitted in 
accordance with 40 CFR 63.10031(f)(4) or 40 CFR 63.10031(h), as 
applicable. This change is necessary to cover initial Notifications of 
Compliance Status for both new and existing EGUs. The interim reporting 
process described in 40 CFR 63.10031(f)(4) and the on-going reporting 
process in 40 CFR 63.10031(h) require these Notifications to be 
submitted as PDF files, through ECMPS.
    (e) Sections 40 CFR 63.10011(g)(3), 40 CFR 63.10021(i), and two 
sentences in Items 3 and 4 of Table 3 are revised to be consistent with 
40 CFR 63.10031(i) and Table 8. For EGU owners or operators relying on 
paragraph (2) of the definition of startup in 40 CFR 63.10042, 40 CFR 
63.10031(i) retains the requirement for the parametric data and other 
information in 40 CFR 63.10031(c)(5) be included in the semiannual 
compliance reports, for startup and shutdown incidents that occur 
during the interim reporting period. However, in view of the phase-out 
of the semiannual compliance reports, for startup and shutdown 
incidents that occur during each subsequent calendar quarter, starting 
with the first quarter of 2024, the supplementary information in 40 CFR 
63.10031(c)(5)(ii) and 40 CFR 63.10020(e) is required to be provided as 
a separate PDF submittal, along with the quarterly compliance report. 
As previously noted, the requirements in 40 CFR 63.10031(c)(5)(iii), 
(iv), and (v) to report hourly average CEMS and operating parameter 
values for startup and shutdown events are not incorporated into this 
PDF report because they are duplicative of the hourly values reported 
under appendices A through D. Startup and shutdown hours are flagged in 
the quarterly emissions reports and can be identified for auditing 
purposes.
    (f) Paragraphs (e)(9), (f), and (h)(3) of 40 CFR 63.10021 are 
revised as follows. Paragraph (e)(9) is unchanged from the previous 
proposal, except that the December 31, 2017, and January 1, 2018, 
transition dates are replaced with December 31, 2023, and January 1, 
2024, respectively. References to the EPA's ERT and the CEDRI interface 
from paragraph (f) are removed and replaced with a general statement 
requiring all applicable notifications and reports be submitted through 
the ECMPS Client Tool. Three statements are added at the end of 
paragraph (f). The first statement, regarding a submission deadline 
that occurs on a weekend or Federal holiday, extends the deadline to 
the next business day. The second statement addresses a submission 
deadline that occurs when the ECMPS system is offline for maintenance; 
in that case, the deadline is extended until the first business day 
after the system outage. The third statement clarifies that using the 
ECMPS Client Tool to submit a required MATS report or notification 
satisfies the requirement in 40 CFR 63.13 of the General Provisions to 
submit that same report or notification (or the information contained 
in it) to the appropriate EPA Regional office or state agency whose 
delegation request has been approved. Finally, we are removing 
paragraph (h)(3) because it is redundant with paragraph (i) and, 
therefore, unnecessary.
    (g) Previous section 40 CFR 63.10030(e)(7)(i) is removed for the 
following reasons. The requirement in the current rule for an initial 
Notification of Compliance Status to include summarized results of 
annual and triennial performance tests which have not been done yet is 
in an incorrect location. The requirement to submit these test 
summaries belongs in 40 CFR 63.10031, not 40 CFR 63.10030. Text similar 
to 40 CFR 63.10030(e)(7)(i) does, in fact, exist in 40 CFR 63.10031. 
Specifically, 40 CFR 63.10031(c)(7) requires the annual and triennial 
test results be summarized in the semiannual compliance reports. Note, 
however, that when the semiannual compliance reports are phased out in 
2024, the requirement to provide summarized results of these tests does 
not end; the test summaries must be included in the quarterly 
compliance reports under 40 CFR 63.10031(g).
    The requirements of section 40 CFR 63.10030(e)(7)(iii) are amended 
to rectify an inadvertent oversight. In the 2016 Technical Corrections 
rule package, the EPA proposed a set of conditions that would allow an 
EGU owner or operator to submit a request for permission to switch from 
a heat input-based standard to an output-based standard. One of the 
proposed conditions in paragraph (e)(7)(iii)(A)(3) required a 
demonstration of compliance with both emission limits based on 
``performance stack test results completed within 30 days prior to'' 
the request. A commenter objected to limiting this demonstration to 
``stack test'' data and asked the EPA to allow any data collected up to 
45 days prior to the request, including CEMS data, be used. In the 
Response to Comments document, the EPA agreed with these commenters, 
but did not make the necessary changes to paragraph (e)(7)(iii)(A)(3) 
in the final rule. This rule corrects this oversight. In addition, a 
note is added to paragraph (e)(7)(iii) to clarify that requests to 
switch from one standard to the other are made subsequent to, and are 
not part of, the initial Notification of Compliance Status.
    (h) The requirements of 40 CFR 63.10032(a) are amended to include 
references to the recordkeeping required under new appendices C (for PM

[[Page 55756]]

CEMS), D (for PM CPMS), and E (for quarterly compliance reports and 
reference method test data). Also, in view of the move away from 
semiannual compliance reporting to quarterly reporting, the term 
``semiannual compliance report'' is replaced with references to both 
semiannual and quarterly compliance reports in paragraph (a)(1).
    (i) The words ``or out of control period'' are removed from the 
definition of ``monitoring system malfunction or out of control 
period'' in 40 CFR 63.10042 because that definition does not describe 
an out of control period. A separate definition of ``out-of-control 
period'' is added, and that definition is similar with the definition 
provided in the Acid Rain Program definitions at 40 CFR 72.2.
    (j) Table 8 to subpart UUUUU of 40 CFR part 63 is revised to be 
consistent with the amendments to 40 CFR 63.10031 and the proposed 
addition of appendices C, D, and E.
    (k) Finally, the recordkeeping and reporting requirements in Table 
9 to 40 CFR part 63, subpart UUUUU are revised as follows. First, the 
requirement to provide the information in 40 CFR 63.10030(e)(1) through 
(8) is clarified, i.e., it only applies to initial Notifications of 
Compliance Status; subsequent notifications are not required. Second, 
in keeping with the earlier discussion provided in section IV.A of this 
preamble, a statement clarifying that the excess emissions 
recordkeeping and reporting requirements of 40 CFR 63.10(c)(7) and (8) 
and 63.10(e)(3)(v) and (vi) apply through December 31, 2023, when the 
semiannual compliance reports are phased out, is added. On and after 
January 1, 2024, all relevant information is provided in quarterly, as 
opposed to semiannual, reports.

VI. Statutory and Executive Order Reviews

    Additional information about these statutes and Executive Orders 
can be found at https://www.epa.gov/laws-regulations/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.

B. Executive Order 13771: Reducing Regulations and Controlling 
Regulatory Costs

    This action is considered an Executive Order 13771 deregulatory 
action. Details on the estimated cost savings of this final rule can be 
found in the EPA's analysis of the potential costs and benefits 
associated with this action.

C. Paperwork Reduction Act (PRA)

    The information collection activities in this rule have been 
submitted for approval to OMB under the PRA. The Information Collection 
Request (ICR) document that the EPA prepared has been assigned EPA ICR 
number 2137.10. You can find a copy of the ICR in the docket for this 
rule, and it is briefly summarized here. The information collection 
requirements are not enforceable until OMB approves them.
    This rule continues to require collection, recording, and 
submission of data pertinent to demonstrating compliance with rule 
requirements. This action consolidates separate reporting systems into 
one reporting system by 2024; maintains the information already 
required to be collected, recorded, and submitted; and changes the 
submission frequency from semiannual to quarterly while consolidating 
the number and type of reports to be submitted.
    Respondents/affected entities: The respondents are owners or 
operators of fossil fuel-fired EGUs. The United States Standard 
Industrial Classification code for respondents affected by the rule is 
4911 (Electric Services). The corresponding NAICS code is 2211100 
(Electric Power Generation, Transmission, and Distribution).
    Respondent's obligation to respond: Mandatory per 42 U.S.C. 7414 et 
seq.
    Estimated number of respondents: 1,414.
    Frequency of response: Quarterly for compliance reports.
    Total estimated burden: 273,000 hours (per year). Burden is defined 
at 5 CFR 1320.3(b).
    Total estimated cost: Savings of $15,079,000 (per year), includes 
$0 annualized capital or operation and maintenance costs.
    An agency may not conduct or sponsor, and a person is not required 
to respond to, a collection of information unless it displays a 
currently valid OMB control number. The OMB control numbers for the 
EPA's regulations in 40 CFR are listed in 40 CFR part 9. When OMB 
approves this ICR, the Agency will announce that approval in the 
Federal Register and publish a technical amendment to 40 CFR part 9 to 
display the OMB control number for the approved information collection 
activities contained in this final rule.

D. Regulatory Flexibility Act (RFA)

    I certify that this action will not have a significant economic 
impact on a substantial number of small entities under the RFA. In 
making this determination, the impact of concern is any significant 
adverse economic impact on small entities. An agency may certify that a 
rule will not have a significant economic impact on a substantial 
number of small entities if the rule relieves regulatory burden, has no 
net burden, or otherwise has a positive economic effect on the small 
entities subject to the rule. For purposes of assessing the impacts of 
this rule on small entities, the EPA considered small entities to be 
defined as: (1) A small business that is an electric utility producing 
4 billion kilowatt-hours or less as defined by NAICS codes 221122 
(fossil fuel-fired electric utility steam generating units) and 921150 
(fossil fuel-fired electric utility steam generating units in Indian 
country); (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. As required by the RFA, the EPA 
proposed using this alternative definition in the Federal Register of 
May 3, 2011, 76 FR 25083, sought public comment, consulted with the 
Small Business Administration and finalized the alternative definition 
in the Federal Register of February 16, 2012, 77 FR 9433. As stated in 
that document, the alternative definition would apply to this 
regulation. This action reduces annual burden on small and large 
entities. We have, therefore, concluded that this action will relieve 
regulatory burden for all directly regulated small entities.

E. Unfunded Mandates Reform Act (UMRA)

    This action does not contain an unfunded mandate of $100 million or 
more as described in UMRA, 2 U.S.C. 1531-1538, and does not 
significantly or uniquely affect small governments. As described 
earlier, this action reduces annual burden on governments already 
subject to MATS; as a result, we have determined that this action will 
not result in any ``significant'' adverse economic impact for small 
governments.

[[Page 55757]]

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. As described earlier, this action has no 
substantial direct effect on Indian tribes already subject to MATS, 
since this action reduces their annual burden. 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 Concerning Regulations 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 that this action is not subject to Executive Order 
12898 (59 FR 7629, February 16, 1994) because it does not establish an 
environmental health or safety standard. This regulatory action revises 
the way in which information is reported to the Agency, increasing 
submission frequency and making adaptions so that just one reporting 
system can be used, but reducing overall burden; this regulatory action 
does not have any impact on human health or the environment.

L. Congressional Review Act (CRA)

    This action is subject to the CRA, and the EPA will submit a rule 
report to each House of the Congress and to the Comptroller General of 
the United States. This action is not a ``major rule'' as defined by 5 
U.S.C. 804(2).

List of Subjects in 40 CFR Part 63

    Environmental protection, Administrative practice and procedure, 
Air pollution control, Hazardous substances, Intergovernmental 
relations, Reporting and recordkeeping requirements.

Andrew Wheeler,
Administrator.

    For the reasons set forth in the preamble, EPA amends 40 CFR part 
63 as follows:

PART 63--NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS 
FOR SOURCE CATEGORIES

0
1. The authority citation for part 63 continues to read as follows:

    Authority:  42 U.S.C. 7401 et seq.

Subpart UUUUU--National Emission Standards for Hazardous Air 
Pollutants: Coal- and Oil-Fired Electric Utility Steam Generating 
Units


Sec.  63.10000   [Amended]

0
2. In Sec.  63.10000, paragraph (d)(5)(vi) is amended by adding the 
words ``where appropriate,'' immediately after the words ``CMS that is 
out of control consistent with section 63.8(c)(7)(i).''

0
3. Section 63.10005 is amended by:
0
a. Revising the first sentence in paragraph (a)(2) introductory text;
0
b. Revising paragraph (b) introductory text; and
0
c. Revising paragraph (h)(3)(iii).
    The revisions read as follows:


Sec.  63.10005   What are my initial compliance requirements and by 
what date must I conduct them?

    (a) * * *
    (2) To demonstrate initial compliance using either a CMS that 
measures HAP concentrations directly (i.e., an Hg, HCl, or HF CEMS, or 
a sorbent trap monitoring system) or an SO2 or PM CEMS, the 
initial performance test shall consist of 30- or, if applicable for Hg, 
90-boiler operating days. * * *
* * * * *
    (b) Performance testing requirements. If you choose to use 
performance testing to demonstrate initial compliance with the 
applicable emissions limits in Tables 1 and 2 to this subpart for your 
EGUs, you must conduct the tests according to 40 CFR 63.10007 and Table 
5 to this subpart. Notwithstanding these requirements, when Table 5 
specifies the use of isokinetic EPA test Method 5, 5D, 26A, or 29 for a 
stack test, if concurrent measurement of the stack gas flow rate or 
moisture content is needed to convert the pollutant concentrations to 
units of the standard, separate determination of these parameters using 
EPA test Method 2 or EPA test Method 4 is not necessary. Instead, the 
stack gas flow rate and moisture content can be determined from data 
that are collected during the EPA test Method 5, 5D, 6, 26A, or 29 test 
(e.g., pitot tube (delta P) readings, moisture collected in the 
impingers, etc.). For the purposes of the initial compliance 
demonstration, you may use test data and results from a performance 
test conducted prior to the date on which compliance is required as 
specified in 40 CFR 63.9984, provided that the following conditions are 
fully met:
* * * * *
    (h) * * *
    (3) * * *
    (iii) Calculate the average Hg concentration, in [micro]g/m\3\ (dry 
basis), for each of LEE test runs comprising the 30- (or 90-) boiler 
operating day performance test, as the arithmetic average of all Method 
30B sorbent trap results from the LEE test period. Also calculate, as 
applicable, the average values of CO2 or O2 
concentration, stack gas flow rate, stack gas moisture content, and 
gross output for the LEE test period. Then:
* * * * *

0
4. Section 63.10009 is amended by:
0
a. Revising in paragraph (a)(2) the second, third, and last sentences;
0
b. In paragraph (b)(2):
0
i. In the introductory text, removing the words ``for pollutants other 
than Hg'';
0
ii. In the definition for ``Heri'' adding the words ``or 
sorbent trap monitoring system'' after the words ``unit i's CEMS''; and
0
c. In paragraph (b)(3) revising ``Equation 3a'' and ``Equation 3b.''
    The revisions read as follows:


Sec.  63.10009   May I use emissions averaging to comply with this 
subpart?

    (a) * * *
    (2) * * * Note that except for the alternate Hg emissions limit 
from EGUs in the ``unit designed for coal >= 8,300 Btu/lb'' 
subcategory, the averaging time for emissions averaging for pollutants 
is 30-group boiler operating days (rolling

[[Page 55758]]

daily) using data from CEMS and sorbent trap monitoring (for Hg), or a 
combination of data from CEMS and emissions testing (for other 
pollutants). The averaging time for emissions averaging for the 
alternate Hg limit (equal to or less than 1.0 lb/TBtu or 1.1E-2 lb/GWh) 
from EGUs in the ``unit designed for coal >= 8,300 Btu/lb'' subcategory 
is 90-group boiler operating days (rolling daily) using data from CEMS, 
sorbent trap monitoring, or a combination of data from CEMS and sorbent 
trap monitoring.
    * * * You must calculate the weighted average emissions rate for 
the group in accordance with the procedures in this paragraph using the 
data from all units in the group including any that operate fewer than 
30 (or 90) of the preceding 30- (or 90-) group boiler operating days.
* * * * *
    (b) * * *
    (3) * * *
    [GRAPHIC] [TIFF OMITTED] TR09SE20.000
    
Where:

Heri = Hourly emission rate from unit i's Hg CEMS or Hg 
sorbent trap monitoring system for the preceding 90-group boiler 
operating days,
Rmi = Hourly heat input or gross output from unit i for 
the preceding 90-group boiler operating days,
p = Number of EGUs in the emissions averaging group,
n = Number of hours that hourly rates are collected over the 90-
group boiler operating days.
[GRAPHIC] [TIFF OMITTED] TR09SE20.001

Where:

Heri = Hourly emission rate from unit i's Hg CEMS or Hg 
sorbent trap monitoring system for the preceding 90-group boiler 
operating days,
Smi = Steam generation in units of pounds from unit i 
that uses Hg CEMS or Hg sorbent trap monitoring for the preceding 
90-group boiler operating days,
Cfmi = Conversion factor, calculated from the most recent 
compliance test results, in units of heat input per pound of steam 
generated or gross output per pound of steam generated, from unit i 
that uses Hg CEMS or sorbent trap monitoring from the preceding 90-
group boiler operating days,
p = Number of EGUs in the emissions averaging group,
n = Number of hours that hourly rates are collected over the 90-
group boiler operating days.
* * * * *

0
5. Section 63.10010 is amended by revising paragraphs (h)(5), (6), (7), 
(i), and (j)(4) to read as follows:


Sec.  63.10010   What are my monitoring, installation, operation, and 
maintenance requirements?

* * * * *
    (h) * * *
    (5) You must collect data using the PM CPMS at all times the 
process unit is operating and at the intervals specified in paragraph 
(h)(1)(ii) of this section, except for required monitoring system 
quality assurance or quality control activities (including, as 
applicable, calibration checks and required zero and span adjustments), 
and any scheduled maintenance as defined in your site-specific 
monitoring plan.
    (6) You must use all the data collected during all boiler operating 
hours in assessing the compliance with your operating limit except:
    (i) Any data recorded during periods of monitoring system 
malfunctions or repairs associated with monitoring system malfunctions. 
You must report any monitoring system malfunctions as deviations in 
your compliance reports under 40 CFR 63.10031(c) or (g) (as 
applicable);
    (ii) Any data recorded during periods when the monitoring system is 
out-of-control (as specified in your site-specific monitoring plan), 
repairs associated with periods when the monitoring system is out of 
control, or required monitoring system quality assurance or quality 
control activities conducted during out-of-control periods. You must 
report any such periods as deviations in your compliance reports under 
40 CFR 63.10031(c) or (g) (as applicable);
    (iii) Any data recorded during required monitoring system quality 
assurance or quality control activities that temporarily interrupt the 
measurement of output data from the PM CPMS; and
    (iv) Any data recorded during periods of startup or shutdown.
    (7) You must record and report the results of PM CPMS system 
performance audits, in accordance with 40 CFR 63.10031(k). You must 
also record and make available upon request the dates and duration of 
periods from when the PM CPMS is out of control until completion of the 
corrective actions necessary to return the PM CPMS to operation 
consistent with your site-specific monitoring plan.
    (i) If you choose to comply with the PM filterable emissions limit 
in lieu of metal HAP limits, you may choose to install, certify, 
operate, and maintain a PM CEMS and record and report the output of the 
PM CEMS as specified in paragraphs (i)(1) through (8) of this section. 
Compliance with the applicable PM emissions limit in Table 1 or 2 to 
this subpart is determined on a 30-boiler operating day rolling average 
basis.
    (1) You must install and certify your PM CEMS according to section 
4 of appendix C to this subpart.
    (2) You must operate, maintain, and quality-assure the data from 
your PM

[[Page 55759]]

CEMS according to section 5 of appendix C to this subpart.
    (3) You must reduce the data from your PM CEMS to hourly averages 
in accordance with section 6.1 of appendix C to this subpart.
    (4) You must collect data using the PM CEMS at all times the 
process unit is operating and at the intervals specified in paragraph 
(a) of this section, except for required monitoring system quality 
assurance or quality control activities and any scheduled maintenance 
as defined in your site-specific monitoring plan.
    (5) You must use all the data collected during all boiler operating 
hours in assessing the compliance with your operating limit except:
    (i) Any data recorded during periods of monitoring system 
malfunctions and repairs associated with monitoring system 
malfunctions. You must report any monitoring system malfunctions as 
deviations in your compliance reports under 40 CFR 63.10031(c) or (g) 
(as applicable);
    (ii) Any data recorded during periods when the monitoring system is 
out-of-control (as specified in appendix C to this subpart), repairs 
associated with periods when the monitoring system is out of control, 
or required monitoring system quality assurance or quality control 
activities conducted during out-of-control periods. You must report any 
such periods as deviations in your compliance reports under 40 CFR 
63.10031(c) or (g) (as applicable);
    (iii) Any data recorded during required monitoring system quality 
assurance, quality control, or maintenance activities that temporarily 
interrupt the measurement of emissions (e.g., calibrations, certain 
audits, routine probe maintenance); and
    (iv) Any data recorded during periods of startup or shutdown.
    (6) You must keep records and report data from your PM CEMS in 
accordance with section 7 of appendix C to this subpart.
    (7) You must record and make available upon request the dates and 
duration of periods when the PM CEMS is out-of-control to completion of 
the corrective actions necessary to return the PM CEMS to operation 
consistent with your site-specific monitoring plan.
    (8) You must calculate each 30-boiler operating day rolling average 
PM emission rate in units of the applicable emissions limit in Table 1 
or 2 to this subpart, in accordance with section 6.2.4 of appendix C to 
this subpart.
    (j) * * *
    (4) You must collect data using the HAP metals CEMS at all times 
the process unit is operating and at the intervals specified in 
paragraph (a) of this section, except for required monitoring system 
quality assurance or quality control activities, and any scheduled 
maintenance as defined in your site-specific monitoring plan.
    (i) You must use all the data collected during all boiler operating 
hours in assessing the compliance with your emission limit except:
    (A) Any data collected during periods of monitoring system 
malfunctions and repairs associated with monitoring system 
malfunctions. You must report any monitoring system malfunctions as 
deviations in your compliance reports under 40 CFR 63.10031(c) or (g) 
(as applicable);
    (B) Any data collected during periods when the monitoring system is 
out of control as specified in your site-specific monitoring plan, 
repairs associated with periods when the monitoring system is out of 
control, or required monitoring system quality assurance or quality 
control activities conducted during out-of-control periods. You must 
report any out of control periods as deviations in your compliance 
reports under 40 CFR 63.10031(c) or (g) (as applicable);
    (C) Any data recorded during required monitoring system quality 
assurance or quality control activities that temporarily interrupt the 
measurement of emissions (e.g., calibrations, certain audits, routine 
probe maintenance); and
    (D) Any data recorded during periods of startup or shutdown.
    (ii) You must record and report the results of HAP metals CEMS 
system performance audits, in accordance with 40 CFR 63.10031(k). You 
must also record and make available upon request the dates and duration 
of periods when the HAP metals CEMS is out of control to completion of 
the corrective actions necessary to return the HAP metals CEMS to 
operation consistent with your site-specific performance evaluation and 
quality control program plan.
* * * * *

0
6. Section 63.10011 is amended by revising paragraphs (e) and (g)(3) to 
read as follows:


Sec.  63.10011   How do I demonstrate initial compliance with the 
emissions limits and work practice standards?

* * * * *
    (e) You must submit a Notification of Compliance Status in 
accordance with 40 CFR 63.10031(f)(4) or (h), as applicable, containing 
the results of the initial compliance demonstration, as specified in 40 
CFR 63.10030(e).
* * * * *
    (g) * * *
    (3) You must report the emissions data recorded during startup and 
shutdown. If you are relying on paragraph (2) of the definition of 
startup in 40 CFR 63.10042, then for startup and shutdown incidents 
that occur on or prior to December 31, 2023, you must also report the 
applicable supplementary information in 40 CFR 63.10031(c)(5) in the 
semiannual compliance report. For startup and shutdown incidents that 
occur on or after January 1, 2024, you must provide the applicable 
information in 40 CFR 63.10031(c)(5)(ii) and 40 CFR 63.10020(e) 
quarterly, in PDF files, in accordance with 40 CFR 63.10031(i).
* * * * *

0
7. Section 63.10020 is amended by revising paragraphs (a), (b), and (d) 
to read as follows:


Sec.  63.10020   How do I monitor and collect data to demonstrate 
continuous compliance?

    (a) You must monitor and collect data according to this section and 
the site-specific monitoring plan required by Sec.  63.10000(d).
    (b) You must operate the monitoring system and collect data at all 
required intervals at all times that the affected EGU is operating, 
except for required monitoring system quality assurance or quality 
control activities, including, as applicable, calibration checks and 
required zero and span adjustments, and any scheduled maintenance as 
defined in your site-specific monitoring plan. You are required to 
affect monitoring system repairs in response to monitoring system 
malfunctions and to return the monitoring system to operation as 
expeditiously as practicable.
* * * * *
    (d) Periods of monitoring system malfunctions or monitoring system 
out-of-control periods, repairs associated with monitoring system 
malfunctions or monitoring system out-of-control periods, and required 
monitoring system quality assurance or quality control activities 
excluding zero and span checks must be reported as time the monitor was 
inoperative (downtime) under 63.10(c). Failure to collect required 
quality-assured data during monitoring system malfunctions, monitoring 
system out-of-control periods, or repairs associated with monitoring 
system malfunctions or monitoring system out-of-control periods is a 
deviation from the monitoring requirements.
* * * * *

0
8. Section 63.10021 is amended by:
0
a. Revising paragraphs (e)(9) and (f);
0
b. Removing and reserving paragraph (h)(3); and

[[Page 55760]]

0
c. Revising paragraph (i).
    The revisions read as follows:


Sec.  63.10021   How do I demonstrate continuous compliance with the 
emission limitations, operating limits, and work practice standards?

* * * * *
    (e) * * *
    (9) Prior to January 1, 2024, report the tune-up date 
electronically, in a PDF file, in your semiannual compliance report, as 
specified in 40 CFR 63.10031(f)(4) and (6) and, if requested by the 
Administrator, in hard copy, as specified in 40 CFR 63.10031(f)(5). On 
and after January 1, 2024, report the tune-up date electronically in 
your quarterly compliance report, in accordance with 40 CFR 63.10031(g) 
and section 10.2 of appendix E to this subpart. The tune-up report date 
is the date when tune-up requirements in paragraphs (e)(6) and (7) of 
this section are completed.
* * * * *
    (f) You must submit the applicable reports and notifications 
required under 40 CFR 63.10031(a) through (k) to the Administrator 
electronically, using EPA's Emissions Collection and Monitoring Plan 
System (ECMPS) Client Tool. If the final date of any time period (or 
any deadline) for any of these submissions falls on a weekend or a 
Federal holiday, the time period shall be extended to the next business 
day. Moreover, if the EPA Host System supporting the ECMPS Client Tool 
is offline and unavailable for submission of reports for any part of a 
day when a report would otherwise be due, the deadline for reporting is 
automatically extended until the first business day on which the system 
becomes available following the outage. Use of the ECMPS Client Tool to 
submit a report or notification required under this subpart satisfies 
any requirement under subpart A of this part to submit that same report 
or notification (or the information contained in it) to the appropriate 
EPA Regional office or state agency whose delegation request has been 
approved.
* * * * *
    (i) If you are relying on paragraph 2 of the definition of startup 
in 40 CFR 63.10042, you must provide reports concerning activities and 
periods of startup and shutdown that occur on or prior to January 1, 
2024, in accordance with 40 CFR 63.10031(c)(5), in your semiannual 
compliance report. For startup and shutdown incidents that occur on and 
after January 1, 2024, you must provide the applicable information 
referenced in 40 CFR 63.10031(c)(5)(ii) and 40 CFR 63.10020(e) 
quarterly, in PDF files, in accordance with 40 CFR 63.10031(i).

0
9. Section 63.10030 is amended by:
0
a. In paragraph (e) introductory text revising the last sentence;
0
b. Revising paragraph (e)(7) introductory text;
0
c. Removing and reserving paragraph (e)(7)(i);
0
d. Revising paragraph (e)(7)(iii) introductory text;
0
e. Revising paragraph (e)(7)(iii)(A)(3);
0
f. Adding in paragraph (e)(7)(iii)(B) the word ``must'' after the word 
``You''; and
0
g. Adding in paragraph (e)(7)(iii)(C) the word ``must'' after the word 
``you''.
    The revisions and additions read as follows:


Sec.  63.10030   What notifications must I submit and when?

* * * * *
    (e) * * * The Notification of Compliance Status report must contain 
all of the information specified in paragraphs (e)(1) through (8) of 
this section, that applies to your initial compliance strategy.
* * * * *
    (7) Except for requests to switch from one emission limit to 
another, as provided in paragraph (e)(7)(iii) of this section, your 
initial notification of compliance status shall also include the 
following information:
* * * * *
    (iii) For each of your existing EGUs, identification of each 
emissions limit specified in Table 2 to this subpart with which you 
plan to comply initially. (Note: If, at some future date, you wish to 
switch from the limit specified in your initial notification of 
compliance status, you must follow the procedures and meet the 
conditions of paragraphs (e)(7)(iii)(A) through (C) of this section).
    (A) * * *
    (3) Your request includes performance stack test results or valid 
CMS data, obtained within 45 days prior to the date of your submission, 
demonstrating that each EGU or EGU emissions averaging group is in 
compliance with both the mass per heat input limit and the mass per 
gross output limit;
* * * * *

0
10. Section 63.10031 is amended by:
0
a. Revising paragraphs (a), (b) introductory text, (b)(1), (2), (4), 
(5);
0
b. Adding paragraph (b)(6);
0
c. Revising paragraph (c) introductory text;
0
d. Removing and reserving paragraphs (c)(5)(iii), (c)(5)(iv), and 
(c)(5)(v);
0
e. Adding paragraph (c)(10);
0
f. Revising paragraphs (d), (e), (f) introductory text, (f)(1), and 
(2);
0
g. Removing and reserving paragraph (f)(3);
0
h. Revising paragraphs (f)(4), (f)(6) introductory text, (f)(6)(vii), 
(f)(6)(xi), and (g); and
0
i. Adding paragraphs (h), (i), (j) and (k), to read as follows:


Sec.  63.10031   What reports must I submit and when?

    (a) You must submit each report in this section that applies to 
you.
    (1) If you are required to (or elect to) monitor Hg emissions 
continuously, you must meet the electronic reporting requirements of 
appendix A to this subpart.
    (2) If you elect to monitor HCl and/or HF emissions continuously, 
you must meet the electronic reporting requirements of appendix B to 
this subpart. Notwithstanding this requirement, if you opt to certify 
your HCl monitor according to Performance Specification 18 in appendix 
B to part 60 of this chapter and to use Procedure 6 in appendix F to 
part 60 of this chapter for on-going QA of the monitor, then, on and 
prior to December 31, 2023, report only hourly HCl emissions data and 
the results of daily calibration drift tests and relative accuracy test 
audits (RATAs) performed on or prior to that date; keep records of all 
of the other required certification and QA tests and report them, 
starting in 2024.
    (3) If you elect to monitor filterable PM emissions continuously, 
you must meet the electronic reporting requirements of appendix C to 
this subpart. Electronic reporting of hourly PM emissions data shall 
begin with the later of the first operating hour on or after January 1, 
2024; or the first operating hour after completion of the initial PM 
CEMS correlation test.
    (4) If you elect to demonstrate continuous compliance using a PM 
CPMS, you must meet the electronic reporting requirements of appendix D 
to this subpart. Electronic reporting of the hourly PM CPMS output 
shall begin with the later of the first operating hour on or after 
January 1, 2024; or the first operating hour after completion of the 
initial performance stack test that establishes the operating limit for 
the PM CPMS.
    (5) If you elect to monitor SO2 emission rate 
continuously as a surrogate for HCl, you must use the ECMPS Client Tool 
to submit the following information to EPA (except where it is already 
required to be reported or has been previously provided under the Acid 
Rain Program or another emissions reduction program that requires the 
use of part 75 of this chapter):

[[Page 55761]]

    (i) Monitoring plan information for the SO2 CEMS and for 
any additional monitoring systems that are required to convert 
SO2 concentrations to units of the emission standard, in 
accordance with sections 75.62 and 75.64(a)(4) of this chapter;
    (ii) Certification, recertification, quality-assurance, and 
diagnostic test results for the SO2 CEMS and for any 
additional monitoring systems that are required to convert 
SO2 concentrations to units of the emission standard, in 
accordance with section 75.64(a)(5); and
    (iii) Quarterly electronic emissions reports. You must submit an 
electronic quarterly report within 30 days after the end of each 
calendar quarter, starting with a report for the calendar quarter in 
which the initial 30 boiler operating day performance test begins. Each 
report must include the following information:
    (A) The applicable operating data specified in section 75.57(b) of 
this chapter;
    (B) An hourly data stream for the unadjusted SO2 
concentration (in ppm, rounded to one decimal place), and separate 
unadjusted hourly data streams for the other parameters needed to 
convert the SO2 concentrations to units of the standard. 
(Note: If a default moisture value is used in the emission rate 
calculations, an hourly data stream is not required for moisture; 
rather, the default value must be reported in the electronic monitoring 
plan.);
    (C) An hourly SO2 emission rate data stream, in units of 
the standard (i.e., lb/MMBtu or lb/MWh, as applicable), calculated 
according to 40 CFR 63.10007(e) and (f)(1), rounded to the same 
precision as the emission standard (i.e., with one leading non-zero 
digit and one decimal place), expressed in scientific notation. Use the 
following rounding convention: If the digit immediately following the 
first decimal place is 5 or greater, round the first decimal place 
upward (increase it by one); if the digit immediately following the 
first decimal place is 4 or less, leave the first decimal place 
unchanged;
    (D) The results of all required daily quality-assurance tests of 
the SO2 monitor and the additional monitors used to convert 
SO2 concentration to units of the standard, as specified in 
appendix B to part 75 of this chapter; and
    (E) A compliance certification, which includes a statement, based 
on reasonable inquiry of those persons with primary responsibility for 
ensuring that all SO2 emissions from the affected EGUs under 
this subpart have been correctly and fully monitored, by a responsible 
official with that official's name, title, and signature, certifying 
that, to the best of his or her knowledge, the report is true, 
accurate, and complete. You must submit such a compliance certification 
statement in support of each quarterly report.
    (b) You must submit semiannual compliance reports according to the 
requirements in paragraphs (b)(1) through (5) of this section.
    (1) The first compliance report must cover the period beginning on 
the compliance date that is specified for your affected source in 40 
CFR 63.9984 (or, if applicable, the extended compliance date approved 
under 40 CFR 63.6(i)(4)) and ending on June 30 or December 31, 
whichever date is the first date that occurs at least 180 days after 
the compliance date that is specified for your source in 40 CFR 63.9984 
(or, if applicable, the extended compliance date approved under 40 CFR 
63.6(i)(4)).
    (2) The first compliance report must be submitted electronically no 
later than July 31 or January 31, whichever date is the first date 
following the end of the first calendar half after the compliance date 
that is specified for your source in 40 CFR 63.9984 (or, if applicable, 
the extended compliance date approved under 40 CFR 63.6(i)(4)).
* * * * *
    (4) Each subsequent compliance report must be submitted 
electronically no later than July 31 or January 31, whichever date is 
the first date following the end of the semiannual reporting period.
    (5) For each affected source that is subject to permitting 
regulations pursuant to part 70 or part 71 of this chapter, and if the 
permitting authority has established dates for submitting semiannual 
reports pursuant to 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 
71.6(a)(3)(iii)(A), through the reporting period that ends December 31, 
2023, you may submit the first and subsequent compliance reports 
according to the dates the permitting authority has established instead 
of according to the dates in paragraphs (b)(1) through (4) of this 
section.
    (6) The final semiannual compliance report shall cover the 
reporting period from July 1, 2023, through December 31, 2023. 
Quarterly compliance reports shall be submitted thereafter, in 
accordance with paragraph (g) of this section, starting with a report 
covering the first calendar quarter of 2024.
    (c) The semiannual compliance report must contain the information 
required in paragraphs (c)(1) through (10) of this section.
* * * * *
    (10) If you had any process or control equipment malfunction(s) 
during the reporting period, you must include the number, duration, and 
a brief description for each type of malfunction which occurred during 
the semiannual reporting period which caused or may have caused any 
applicable emission limitation to be exceeded.
    (d) Excess emissions and deviation reporting. For EGUs whose owners 
or operators rely on a CMS to comply with an emissions or operating 
limit, the semiannual compliance reports described in paragraph (c) of 
this section must include the excess emissions and monitor downtime 
summary report described in 40 CFR 63.10(e)(3)(vi). However, starting 
with the first calendar quarter of 2024, reporting of the information 
under 40 CFR 63.10(e)(3)(vi) (and under paragraph (e)(3)(v), if the 
applicable excess emissions and/or monitor downtime threshold is 
exceeded) is discontinued for all CMS, and you must, instead, include 
in the quarterly compliance reports described in paragraph (g) of this 
section the applicable data elements in section 13 of appendix E to 
this subpart for any ``deviation'' (as defined in 40 CFR 63.10042 and 
elsewhere in this subpart) that occurred during the calendar quarter. 
If there were no deviations, you must include a statement to that 
effect in the quarterly compliance report.
    (e) Each affected source that has obtained a title V operating 
permit pursuant to part 70 or part 71 of this chapter must report all 
deviations as defined in this subpart in the semiannual monitoring 
report required by 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 
71.6(a)(3)(iii)(A). If an affected source submits a semiannual 
compliance report pursuant to paragraphs (c) and (d) of this section, 
or two quarterly compliance reports covering the appropriate calendar 
half pursuant to paragraph (g) of this section, along with, or as part 
of, the semiannual monitoring report required by 40 CFR 
70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A), and the compliance 
report(s) includes all required information concerning deviations from 
any emission limit, operating limit, or work practice requirement in 
this subpart, submission of the compliance report(s) satisfies any 
obligation to report the same deviations in the semiannual monitoring 
report. Submission of the compliance report(s) does not otherwise 
affect any obligation the affected source may have to report deviations 
from permit requirements to the permit authority.
    (f) For each performance stack test completed prior to January 1, 
2024, (including 30- (or 90-) boiler operating

[[Page 55762]]

day Hg LEE demonstration tests and PM tests to establish operating 
limits for PM CPMS), you must submit a PDF test report in accordance 
with paragraph (f)(6) of this section, no later than 60 days after the 
date on which the testing is completed. For each test completed on or 
after January 1, 2024, in accordance with 40 CFR 63.10031(g), submit 
the applicable reference method information in sections 17 through 31 
of appendix E to this subpart along with the quarterly compliance 
report for the calendar quarter in which the test was completed.
    (1) For each RATA of an Hg, HCl, HF, or SO2 monitoring 
system completed prior to January 1, 2024, and for each PM CEMS 
correlation test, each relative response audit (RRA) and each response 
correlation audit (RCA) of a PM CEMS completed prior to that date, you 
must submit a PDF test report in accordance with paragraph (f)(6) of 
this section, no later than 60 days after the date on which the test is 
completed. For each SO2 or Hg RATA completed on or after 
January 1, 2024, you must submit the applicable reference method 
information in sections 17 through 31 of appendix E to this subpart 
prior to or concurrent with the relevant quarterly emissions report. 
For HCl or HF RATAs, and for correlation tests, RRAs, and RCAs of PM 
CEMS that are completed on or after January 1, 2024, submit the 
appendix E reference method information together with the summarized 
electronic test results, in accordance with section 11.4 of appendix B 
to this subpart or section 7.2.4 of appendix C to this part, as 
applicable.
    (2) If, for a particular EGU or a group of EGUs serving a common 
stack, you have elected to demonstrate compliance using a PM CEMS, an 
approved HAP metals CEMS, or a PM CPMS, you must submit quarterly PDF 
reports in accordance with paragraph (f)(6) of this section, which 
include all of the 30-boiler operating day rolling average emission 
rates derived from the CEMS data or the 30-boiler operating day rolling 
average responses derived from the PM CPMS data (as applicable). The 
quarterly reports are due within 60 days after the reporting periods 
ending on March 31st, June 30th, September 30th, and December 31st. 
Submission of these quarterly reports in PDF files shall end with the 
report that covers the fourth calendar quarter of 2023. Beginning with 
the first calendar quarter of 2024, the compliance averages shall no 
longer be reported separately, but shall be incorporated into the 
quarterly compliance reports described in paragraph (g) of this 
section. In addition to the compliance averages for PM CEMS, PM CPMS, 
and/or HAP metals CEMS, the quarterly compliance reports described in 
paragraph (g) of this section must also include the 30- (or, if 
applicable 90-) boiler operating day rolling average emission rates for 
Hg, HCl, HF, and/or SO2, if you have elected to (or are 
required to) continuously monitor these pollutants. Further, if your 
EGU or common stack is in an averaging plan, your quarterly compliance 
reports must identify all of the EGUs or common stacks in the plan and 
must include all of the 30- (or 90-) group boiler operating day rolling 
weighted average emission rates (WAERs) for the averaging group.
    (3) [Reserved]
    (4) You must submit semiannual compliance reports as required under 
paragraphs (b) through (d) of this section, ending with a report 
covering the semiannual period from July 1 through December 31, 2023, 
and Notifications of Compliance Status as required under section 
63.10030(e), as PDF files. Quarterly compliance reports shall be 
submitted in XML format thereafter, in accordance with paragraph (g) of 
this section, starting with a report covering the first calendar 
quarter of 2024.
* * * * *
    (6) All reports and notifications described in paragraphs (f) 
introductory text, (f)(1), (2), and (4) of this section shall be 
submitted to the EPA in the specified format and at the specified 
frequency, using the ECMPS Client Tool. Each PDF version of a stack 
test report, CEMS RATA report, PM CEMS correlation test report, RRA 
report, and RCA report must include sufficient information to assess 
compliance and to demonstrate that the reference method testing was 
done properly. Note that EPA will continue to accept, as necessary, PDF 
reports that are being phased out at the end of 2023, if the submission 
deadlines for those reports extend beyond December 31, 2023. The 
following data elements must be entered into the ECMPS Client Tool at 
the time of submission of each PDF file:
* * * * *
    (vii) An indication of the type of PDF report or notification being 
submitted;
* * * * *
    (xi) The date the performance test was completed (if applicable) 
and the test number (if applicable); and
* * * * *
    (g) Starting with a report for the first calendar quarter of 2024, 
you must use the ECMPS Client Tool to submit quarterly electronic 
compliance reports. Each quarterly compliance report shall include the 
applicable data elements in sections 2 through 13 of appendix E to this 
subpart. For each stack test summarized in the compliance report, you 
must also submit the applicable reference method information in 
sections 17 through 31 of appendix E to this subpart. The compliance 
reports and associated appendix E information must be submitted no 
later than 60 days after the end of each calendar quarter.
    (h) On and after January 1, 2024, initial Notifications of 
Compliance Status (if any) shall be submitted in accordance with 40 CFR 
63.9(h)(2)(ii), as PDF files, using the ECMPS Client Tool. The 
applicable data elements in paragraphs (f)(6)(i) through (xii) of this 
section must be entered into ECMPS with each Notification.
    (i) If you have elected to use paragraph (2) of the definition of 
``startup'' in 40 CFR 63.10042, then, for startup and shutdown 
incidents that occur on or prior to December 31, 2023, you must include 
the information in 40 CFR 63.10031(c)(5) in the semiannual compliance 
report, in a PDF file. If you have elected to use paragraph (2) of the 
definition of ``startup'' in 40 CFR 63.10042, then, for startup and 
shutdown event(s) that occur on or after January 1, 2024, you must use 
the ECMPS Client Tool to submit the information in 40 CFR 
63.10031(c)(5) and 40 CFR 63.10020(e) along with each quarterly 
compliance report, in a PDF file, starting with a report for the first 
calendar quarter of 2024. The applicable data elements in paragraphs 
(f)(6)(i) through (xii) of this section must be entered into ECMPS with 
each startup and shutdown report.
    (j) If you elect to use a certified PM CEMS to monitor PM emissions 
continuously to demonstrate compliance with this subpart and have begun 
recording valid data from the PM CEMS prior to November 9, 2020, you 
must use the ECMPS Client Tool to submit a detailed report of your PS 
11 correlation test (see appendix B to part 60 of this chapter) in a 
PDF file no later than 60 days after that date. For a correlation test 
completed on or after November 9, 2020, but prior to January 1, 2024, 
you must submit the PDF report no later than 60 days after the date on 
which the test is completed. For a correlation test completed on or 
after January 1, 2024, you must submit the PDF report according to 
section 7.2.4 of appendix C to this subpart. The applicable data 
elements in paragraph (f)(6)(i) through (xii) of this section must be 
entered into ECMPS with the PDF report.
    (k) If you elect to demonstrate compliance using a PM CPMS or an

[[Page 55763]]

approved HAP metals CEMS, you must submit quarterly reports of your QA/
QC activities (e.g., calibration checks, performance audits), in a PDF 
file, beginning with a report for the first quarter of 2024, if the PM 
CPMS or HAP metals CEMS is used for the compliance demonstration in 
that quarter. Otherwise, submit a report for the first calendar quarter 
in which the PM CPMS or HAP metals CEMS is used to demonstrate 
compliance. These reports are due no later than 60 days after the end 
of each calendar quarter. The applicable data elements in paragraph 
(f)(6)(i) through (xii) of this section must be entered into ECMPS with 
the PDF report.

0
11. Section 63.10032 is amended by revising paragraphs (a) introductory 
text and (a)(1) to read as follows:


Sec.  63.10032   What records must I keep?

    (a) You must keep records according to paragraphs (a)(1) and (2) of 
this section. If you are required to (or elect to) continuously monitor 
Hg and/or HCl and/or HF and/or PM emissions, or if you elect to use a 
PM CPMS, you must keep the records required under appendix A and/or 
appendix B and/or appendix C and/or appendix D to this subpart. If you 
elect to conduct periodic (e.g., quarterly or annual) performance stack 
tests, then, for each test completed on or after January 1, 2024, you 
must keep records of the applicable data elements under 40 CFR 63.7(g). 
You must also keep records of all data elements and other information 
in appendix E to this subpart that apply to your compliance strategy.
    (1) In accordance with 40 CFR 63.10(b)(2)(xiv), a copy of each 
notification or report that you submit to comply with this subpart. You 
must also keep records of all supporting documentation for the initial 
Notifications of Compliance Status, semiannual compliance reports, or 
quarterly compliance reports that you submit.
* * * * *

0
12. Section 63.10042 is amended by:
0
a. In the definition ``Diluent cap'' adding the word ``PM,'' after the 
word ``HF,'';
0
b. In the definition ``Monitoring system malfunction or out of control 
period'' removing the words ``or out of control period''; and
0
c. Adding the definition ``Out of control period'' in alphabetical 
order.
    The addition reads as follows:


Sec.  63.10042  What definitions apply to this subpart?

* * * * *
    Out-of-control period, as it pertains to continuous monitoring 
systems, means any period:
    (1) Beginning with the hour corresponding to the completion of a 
daily calibration or quality assurance audit that indicates that the 
instrument fails to meet the applicable acceptance criteria; and
    (2) Ending with the hour corresponding to the completion of an 
additional calibration or quality assurance audit following corrective 
action showing that the instrument meets the applicable acceptance 
criteria.
* * * * *

0
13. Table 3 to subpart UUUUU is amended by revising the entries ``3. A 
coal-fired, liquid oil-fired (excluding limited-use liquid oil-fired 
subcategory units), or solid oil-derived fuel-fired EGU during 
startup'' and ``4. A coal-fired, liquid oil-fired (excluding limited-
use liquid oil-fired subcategory units), or solid oil-derived fuel-
fired EGU during shutdown'' to read as follows:

      Table 3 to Subpart UUUUU of Part 63--Work Practice Standards
                              * * * * * * *
------------------------------------------------------------------------
       If your EGU is . . .           You must meet the following . . .
------------------------------------------------------------------------
 
                              * * * * * * *
3. A coal-fired, liquid oil-fired   a. You have the option of complying
 (excluding limited-use liquid oil-  using either of the following work
 fired subcategory units), or        practice standards:
 solid oil-derived fuel-fired EGU   (1) If you choose to comply using
 during startup.                     paragraph (1) of the definition of
                                     ``startup'' in Sec.   63.10042, you
                                     must operate all CMS during
                                     startup. Startup means either the
                                     first-ever firing of fuel in a
                                     boiler for the purpose of producing
                                     electricity, or the firing of fuel
                                     in a boiler after a shutdown event
                                     for any purpose. Startup ends when
                                     any of the steam from the boiler is
                                     used to generate electricity for
                                     sale over the grid or for any other
                                     purpose (including on site use).
                                     For startup of a unit, you must use
                                     clean fuels as defined in Sec.
                                     63.10042 for ignition. Once you
                                     convert to firing coal, residual
                                     oil, or solid oil-derived fuel, you
                                     must engage all of the applicable
                                     control technologies except dry
                                     scrubber and SCR. You must start
                                     your dry scrubber and SCR systems,
                                     if present, appropriately to comply
                                     with relevant standards applicable
                                     during normal operation. You must
                                     comply with all applicable
                                     emissions limits at all times
                                     except for periods that meet the
                                     applicable definitions of startup
                                     and shutdown in this subpart. You
                                     must keep records during startup
                                     periods. You must provide reports
                                     concerning activities and startup
                                     periods, as specified in Sec.
                                     63.10011(g) and Sec.   63.10021(h)
                                     and (i). If you elect to use
                                     paragraph (2) of the definition of
                                     startup in 40 CFR 63.10042, you
                                     must report the applicable
                                     information in 40 CFR
                                     63.10031(c)(5) concerning startup
                                     periods as follows: For startup
                                     periods that occur on or prior to
                                     December 31, 2023, in PDF files in
                                     the semiannual compliance report;
                                     for startup periods that occur on
                                     or after January 1, 2024,
                                     quarterly, in PDF files, according
                                     to 40 CFR 63.10031(i).
                                       (2) If you choose to comply using
                                        paragraph (2) of the definition
                                        of ``startup'' in Sec.
                                        63.10042, you must operate all
                                        CMS during startup. You must
                                        also collect appropriate data,
                                        and you must calculate the
                                        pollutant emission rate for each
                                        hour of startup.
                                       For startup of an EGU, you must
                                        use one or a combination of the
                                        clean fuels defined in Sec.
                                        63.10042 to the maximum extent
                                        possible, taking into account
                                        considerations such as boiler or
                                        control device integrity,
                                        throughout the startup period.
                                        You must have sufficient clean
                                        fuel capacity to engage and
                                        operate your PM control device
                                        within one hour of adding coal,
                                        residual oil, or solid oil-
                                        derived fuel to the unit. You
                                        must meet the startup period
                                        work practice requirements as
                                        identified in Sec.
                                        63.10020(e).
                                       Once you start firing coal,
                                        residual oil, or solid oil-
                                        derived fuel, you must vent
                                        emissions to the main stack(s).
                                        You must comply with the
                                        applicable emission limits
                                        beginning with the hour after
                                        startup ends. You must engage
                                        and operate your PM control(s)
                                        within 1 hour of first firing of
                                        coal, residual oil, or solid oil-
                                        derived fuel.

[[Page 55764]]

 
                                       You must start all other
                                        applicable control devices as
                                        expeditiously as possible,
                                        considering safety and
                                        manufacturer/supplier
                                        recommendations, but, in any
                                        case, when necessary to comply
                                        with other standards made
                                        applicable to the EGU by a
                                        permit limit or a rule other
                                        than this subpart that require
                                        operation of the control
                                        devices.
                                       b. Relative to the syngas not
                                        fired in the combustion turbine
                                        of an IGCC EGU during startup,
                                        you must either: (1) Flare the
                                        syngas, or (2) route the syngas
                                        to duct burners, which may need
                                        to be installed, and route the
                                        flue gas from the duct burners
                                        to the heat recovery steam
                                        generator.
                                       c. If you choose to use just one
                                        set of sorbent traps to
                                        demonstrate compliance with the
                                        applicable Hg emission limit,
                                        you must comply with the limit
                                        at all times; otherwise, you
                                        must comply with the applicable
                                        emission limit at all times
                                        except for startup and shutdown
                                        periods.
                                       d. You must collect monitoring
                                        data during startup periods, as
                                        specified in Sec.   63.10020(a)
                                        and (e). You must keep records
                                        during startup periods, as
                                        provided in Sec.  Sec.
                                        63.10021(h) and 63.10032. You
                                        must provide reports concerning
                                        activities and startup periods,
                                        as specified in Sec.  Sec.
                                        63.10011(g), 63.10021(i), and
                                        63.10031. If you elect to use
                                        paragraph (2) of the definition
                                        of startup in 40 CFR 63.10042,
                                        you must report the applicable
                                        information in 40 CFR
                                        63.10031(c)(5) concerning
                                        startup periods as follows: For
                                        startup periods that occur on or
                                        prior to December 31, 2023, in
                                        PDF files in the semiannual
                                        compliance report; for startup
                                        periods that occur on or after
                                        January 1, 2024, quarterly, in
                                        PDF files, according to 40 CFR
                                        63.10031(i).
4. A coal-fired, liquid oil-fired   You must operate all CMS during
 (excluding limited-use liquid oil-  shutdown. You must also collect
 fired subcategory units), or        appropriate data, and you must
 solid oil-derived fuel-fired EGU    calculate the pollutant emission
 during shutdown.                    rate for each hour of shutdown for
                                     those pollutants for which a CMS is
                                     used.
                                    While firing coal, residual oil, or
                                     solid oil-derived fuel during
                                     shutdown, you must vent emissions
                                     to the main stack(s) and operate
                                     all applicable control devices and
                                     continue to operate those control
                                     devices after the cessation of
                                     coal, residual oil, or solid oil-
                                     derived fuel being fed into the EGU
                                     and for as long as possible
                                     thereafter considering operational
                                     and safety concerns. In any case,
                                     you must operate your controls when
                                     necessary to comply with other
                                     standards made applicable to the
                                     EGU by a permit limit or a rule
                                     other than this subpart and that
                                     require operation of the control
                                     devices.
                                    If, in addition to the fuel used
                                     prior to initiation of shutdown,
                                     another fuel must be used to
                                     support the shutdown process, that
                                     additional fuel must be one or a
                                     combination of the clean fuels
                                     defined in Sec.   63.10042 and must
                                     be used to the maximum extent
                                     possible, taking into account
                                     considerations such as not
                                     compromising boiler or control
                                     device integrity.
                                    Relative to the syngas not fired in
                                     the combustion turbine of an IGCC
                                     EGU during shutdown, you must
                                     either: (1) Flare the syngas, or
                                     (2) route the syngas to duct
                                     burners, which may need to be
                                     installed, and route the flue gas
                                     from the duct burners to the heat
                                     recovery steam generator.
                                    You must comply with all applicable
                                     emission limits at all times except
                                     during startup periods and shutdown
                                     periods at which time you must meet
                                     this work practice. You must
                                     collect monitoring data during
                                     shutdown periods, as specified in
                                     Sec.   63.10020(a). You must keep
                                     records during shutdown periods, as
                                     provided in Sec.  Sec.   63.10032
                                     and 63.10021(h). Any fraction of an
                                     hour in which shutdown occurs
                                     constitutes a full hour of
                                     shutdown. You must provide reports
                                     concerning activities and shutdown
                                     periods, as specified in Sec.  Sec.
                                       63.10011(g), 63.10021(i), and
                                     63.10031. If you elect to use
                                     paragraph (2) of the definition of
                                     startup in 40 CFR 63.10042, you
                                     must report the applicable
                                     information in 40 CFR
                                     63.10031(c)(5) concerning shutdown
                                     periods as follows: For shutdown
                                     periods that occur on or prior to
                                     December 31, 2023, in PDF files in
                                     the semiannual compliance report;
                                     for shutdown periods that occur on
                                     or after January 1, 2024,
                                     quarterly, in PDF files, according
                                     to 40 CFR 63.10031(i).
------------------------------------------------------------------------

* * * * *

0
14. Table 8 to subpart UUUUU is revised to read as follows:

       Table 8 to Subpart UUUUU of Part 63--Reporting Requirements
    [In accordance with 40 CFR 63.10031, you must meet the following
   reporting requirements, as they apply to your compliance strategy]
------------------------------------------------------------------------
               You must submit the following reports . . .
-------------------------------------------------------------------------
1. The electronic reports required under 40 CFR 63.10031 (a)(1), if you
 continuously monitor Hg emissions.
2. The electronic reports required under 40 CFR 63.10031 (a)(2), if you
 continuously monitor HCl and/or HF emissions.
    Where applicable, these reports are due no later than 30 days after
     the end of each calendar quarter.
3. The electronic reports required under 40 CFR 63.10031(a)(3), if you
 continuously monitor PM emissions.
    Reporting of hourly PM emissions data using ECMPS shall begin with
     the first operating hour after: January 1, 2024, or the hour of
     completion of the initial PM CEMS correlation test, whichever is
     later.
    Where applicable, these reports are due no later than 30 days after
     the end of each calendar quarter.
4. The electronic reports required under 40 CFR 63.10031(a)(4), if you
 elect to use a PM CPMS.
    Reporting of hourly PM CPMS response data using ECMPS shall begin
     with the first operating hour after January 1, 2024, or the first
     operating hour after completion of the initial performance stack
     test that establishes the operating limit for the PM CPMS,
     whichever is later.
    Where applicable, these reports are due no later than 30 days after
     the end of each calendar quarter.
5. The electronic reports required under 40 CFR 63.10031(a)(5), if you
 continuously monitor SO2 emissions.
    Where applicable, these reports are due no later than 30 days after
     the end of each calendar quarter.

[[Page 55765]]

 
6. PDF reports for all performance stack tests completed prior to
 January 1, 2024 (including 30- or 90-boiler operating day Hg LEE test
 reports and PM test reports to set operating limits for PM CPMS),
 according to the introductory text of 40 CFR 63.10031(f) and 40 CFR
 63.10031(f)(6).
    For each test, submit the PDF report no later than 60 days after the
     date on which testing is completed.
    For a PM test that is used to set an operating limit for a PM CPMS,
     the report must also include the information in 40 CFR
     63.10023(b)(2)(vi).
    For each performance stack test completed on or after January 1,
     2024, submit the test results in the relevant quarterly compliance
     report under 40 CFR 63.10031(g), together with the applicable
     reference method information in sections 17 through 31 of appendix
     E to this subpart.
7. PDF reports for all RATAs of Hg, HCl, HF, and/or SO2 monitoring
 systems completed prior to January 1, 2024, and for correlation tests,
 RRAs and/or RCAs of PM CEMS completed prior to January 1, 2024,
 according to 40 CFR 63.10031(f)(1) and (6).
    For each test, submit the PDF report no later than 60 days after the
     date on which testing is completed.
    For each SO2 or Hg system RATA completed on or after January 1,
     2024, submit the electronic test summary required by appendix A to
     this subpart or part 75 of this chapter (as applicable) together
     with the applicable reference method information in sections 17
     through 30 of appendix E to this subpart, either prior to or
     concurrent with the relevant quarterly emissions report.
    For each HCl or HF system RATA, and for each correlation test, RRA,
     and RCA of a PM CEMS completed on or after January 1, 2024, submit
     the electronic test summary in accordance with section 11.4 of
     appendix B to this subpart or section 7.2.4 of appendix C to this
     part, as applicable, together with the applicable reference method
     information in sections 17 through 30 of appendix E to this
     subpart.
8. Quarterly reports, in PDF files, that include all 30-boiler operating
 day rolling averages in the reporting period derived from your PM CEMS,
 approved HAP metals CEMS, and/or PM CPMS, according to 40 CFR
 63.10031(f)(2) and (6). These reports are due no later than 60 days
 after the end of each calendar quarter.
    The final quarterly rolling averages report in PDF files shall cover
     the fourth calendar quarter of 2023.
    Starting with the first quarter of 2024, you must report all 30-
     boiler operating day rolling averages for PM CEMS, approved HAP
     metals CEMS, PM CPMS, Hg CEMS, Hg sorbent trap systems, HCl CEMS,
     HF CEMS, and/or SO2 CEMS (or 90-boiler operating day rolling
     averages for Hg systems), in XML format, in the quarterly
     compliance reports required under 40 CFR 63.10031(g).
    If your EGU or common stack is in an averaging plan, each quarterly
     compliance report must identify the EGUs in the plan and include
     all of the 30- or 90- group boiler operating day WAERs for the
     averaging group.
    The quarterly compliance reports must be submitted no later than 60
     days after the end of each calendar quarter.
9. The semiannual compliance reports described in 40 CFR 63.10031(c) and
 (d), in PDF files, according to 40 CFR 63.10031(f)(4) and (6). The due
 dates for these reports are specified in 40 CFR 63.10031(b).
    The final semiannual compliance report shall cover the period from
     July 1, 2023, through December 31, 2023.
10. Notifications of compliance status, in PDF files, according to 40
 CFR 63.10031(f)(4) and (6) until December 31, 2023, and according to 40
 CFR 63.10031(h) thereafter.
11. Quarterly electronic compliance reports, in accordance with 40 CFR
 63.10031(g), starting with a report for the first calendar quarter of
 2024. The reports must be in XML format and must include the applicable
 data elements in sections 2 through 13 of appendix E to this subpart.
    These reports are due no later than 60 days after the end of each
     calendar quarter.
12. Quarterly reports, in PDF files, that include the applicable
 information in 40 CFR 63.10031(c)(5)(ii) and 40 CFR 63.10020(e)
 pertaining to startup and shutdown events, starting with a report for
 the first calendar quarter of 2024, if you have elected to use
 paragraph 2 of the definition of startup in 40 CFR 63.10042 (see 40 CFR
 63.10031(i)).
    These PDF reports shall be submitted no later than 60 days after the
     end of each calendar quarter, along with the quarterly compliance
     reports required under 40 CFR 63.10031(g).
13. A test report for the PS 11 correlation test of your PM CEMS, in
 accordance with 40 CFR 63.10031(j).
    If, prior to November 9, 2020, you have begun using a certified PM
     CEMS to demonstrate compliance with this subpart, use the ECMPS
     Client Tool to submit the report, in a PDF file, no later than 60
     days after that date.
    For correlation tests completed on or after November 9, 2020, but
     prior to January 1, 2024, submit the report, in a PDF file, no
     later than 60 days after the date on which the test is completed.
    For correlation tests completed on or after January 1, 2024, submit
     the test results electronically, according to section 7.2.4 of
     appendix C to this subpart, together with the applicable reference
     method data in sections 17 through 31 of appendix E to this
     subpart.
14. Quarterly reports that include the QA/QC activities for your PM CPMS
 or approved HAP metals CEMS (as applicable), in PDF files, according to
 40 CFR 63.10031(k).
    The first report shall cover the first calendar quarter of 2024, if
     the PM CPMS or HAP metals CEMS is in use during that quarter.
     Otherwise, reporting begins with the first calendar quarter in
     which the PM CPMS or HAP metals CEMS is used to demonstrate
     compliance.
    These reports are due no later than 60 days after the end of each
     calendar quarter.
------------------------------------------------------------------------

* * * * *

0
15. Table 9 to subpart UUUUU is amended by:
0
a. Revising the entries ``63.9''and ``63.10(c)(7) and (8)''; and
0
b. Adding the entry ``Sec.  63.10(e)(3)(v) and (vi)''.
    The addition and revision read as follows:

[[Page 55766]]



Table 9 to Subpart UUUUU of Part 63--Applicability of General Provisions
                            to Subpart UUUUU
                             [* * * * * * *]
------------------------------------------------------------------------
                                                     Applies to subpart
             Citation                  Subject              UUUUU
------------------------------------------------------------------------
 
                              * * * * * * *
Sec.   63.9......................  Notification     Yes, except (1) for
                                    Requirements.    the 60-day
                                                     notification prior
                                                     to conducting a
                                                     performance test in
                                                     Sec.   63.9(e);
                                                     instead use a 30-
                                                     day notification
                                                     period per Sec.
                                                     63.10030(d), (2)
                                                     the notification of
                                                     the CMS performance
                                                     evaluation in Sec.
                                                      63.9(g)(1) is
                                                     limited to RATAs,
                                                     and (3) the
                                                     information
                                                     required per Sec.
                                                     63.9(h)(2)(i);
                                                     instead provide the
                                                     applicable
                                                     information in Sec.
                                                       63.10030(e)(1)
                                                     through (8), for
                                                     the initial
                                                     notification of
                                                     compliance status,
                                                     only.
 
                              * * * * * * *
Sec.   63.10(c)(7)...............  Additional       Applies only through
                                    recordkeeping    December 31, 2023.
                                    requirements
                                    for CMS --
                                    identifying
                                    exceedances
                                    and excess
                                    emissions.
Sec.   63.10(c)(8)...............  Additional       Applies only through
                                    recordkeeping    December 31, 2023.
                                    requirements
                                    for CMS--
                                    identifying
                                    exceedances
                                    and excess
                                    emissions.
 
                              * * * * * * *
Sec.   63.10(e)(3)(v) and (vi)...  Excess           Applies only through
                                    emissions and    December 31, 2023.
                                    CMS
                                    performance
                                    reports.
 
                              * * * * * * *
------------------------------------------------------------------------


0
16. Appendix A to subpart UUUUU is amended by revising sections 5.1.1, 
7.1.1.2.1, 7.1.3.3, 7.1.4.3, 7.1.8.2, and 7.2.3.1 to read as follows:

Appendix A to Subpart UUUUU of Part 63--HG Monitoring Provisions

* * * * *

5. Ongoing Quality Assurance (QA) and Data Validation

* * * * *
    5.1.1 Required QA Tests. Periodic QA testing of each Hg CEMS is 
required following initial certification. The required QA tests, the 
test frequencies, and the performance specifications that must be 
met are summarized in Table A-2, below. All tests must be performed 
with the affected unit(s) operating (i.e., combusting fuel), 
however, the daily calibration may optionally be performed off-line. 
The RATA must be performed at normal load, but no particular load 
level is required for the other tests. For each test, follow the 
same basic procedures in section 4.1.1 of this appendix that were 
used for initial certification.
* * * * *

7. Recordkeeping and Reporting

* * * * *
    7.1.1.2.1 Electronic. The electronic monitoring plan records 
must include the following: unit or stack ID number(s); monitoring 
location(s); the Hg monitoring methodologies used; emissions 
controls; Hg monitoring system information, including, but not 
limited to: Unique system and component ID numbers; the make, model, 
and serial number of the monitoring equipment; the sample 
acquisition method; formulas used to calculate Hg emissions; and Hg 
monitor span and range information. The electronic monitoring plan 
shall be evaluated and submitted using the ECMPS Client Tool 
provided by the Clean Air Markets Division in the Office of 
Atmospheric Programs of the EPA.
* * * * *
    7.1.3.3 The hourly Hg concentration, if a quality-assured value 
is obtained for the hour ([micro]g/scm, with one leading non-zero 
digit and one decimal place, expressed in scientific notation). Use 
the following rounding convention: If the digit immediately 
following the first decimal place is 5 or greater, round the first 
decimal place upward (increase it by one); if the digit immediately 
following the first decimal place is 4 or less, leave the first 
decimal place unchanged;
* * * * *
    7.1.4.3 The hourly Hg concentration, if a quality-assured value 
is obtained for the hour ([micro]g/scm, with one leading non-zero 
digit and one decimal place, expressed in scientific notation). Use 
the following rounding convention: If the digit immediately 
following the first decimal place is 5 or greater, round the first 
decimal place upward (increase it by one); if the digit immediately 
following the first decimal place is 4 or less, leave the first 
decimal place unchanged. Note that when a single quality-assured Hg 
concentration value is obtained for a particular data collection 
period, that single concentration value is applied to each operating 
hour of the data collection period.
* * * * *
    7.1.8.2 The hourly Hg emissions rate (lb/TBtu or lb/GWh, as 
applicable), calculated according to section 6.2.1 or 6.2.2 of this 
appendix, rounded to the same precision as the standard (i.e., with 
one leading non-zero digit and one decimal place, expressed in 
scientific notation), if valid values of Hg concentration and all 
other required parameters (stack gas volumetric flow rate, diluent 
gas concentration, electrical load, and moisture data, as 
applicable) are obtained for the hour. Use the following rounding 
convention: If the digit immediately following the first decimal 
place is 5 or greater, round the first decimal place upward 
(increase it by one); if the digit immediately following the first 
decimal place is 4 or less, leave the first decimal place unchanged;
* * * * *
    7.2.3.1 For an EGU that begins reporting hourly Hg 
concentrations with a previously-certified Hg monitoring system, 
submit the monitoring plan information in section 7.1.1.2 of this 
appendix prior to or concurrent with the first required quarterly 
emissions report. For a new EGU, or for an EGU switching to 
continuous monitoring of Hg emissions after having implemented 
another allowable compliance option under this subpart, submit the 
information in section 7.1.1.2 of this appendix at least 21 days 
prior to the start of initial certification testing of the CEMS. 
Also submit the monitoring plan information in section 75.53(g) 
pertaining to any required flow rate, diluent gas, and moisture 
monitoring systems within the applicable time frame specified in 
this section, if the required records are not already in place.
* * * * *

0
17. Appendix B to subpart UUUUU is amended by:
0
a. Revising the heading and introductory text of section 2.3;
0
b. Revising sections 9.4, 10.1.3.3, 10.1.7.2, 10.1.8.1.1, 10.1.8.1.2, 
and 10.1.8.1.3;

[[Page 55767]]

0
c. Adding sections 10.1.8.1.4 through 10.1.8.1.12;
0
d. Revising sections 11.3.1, 11.4 introductory text, and 11.4.1;
0
e. Adding sections 11.4.1.1 through 11.4.1.9;
0
f. Revising section 11.4.2 introductory text;
0
g. Revising sections 11.4.3.11 and 11.4.3.12;
0
h. Re-designating section 11.4.3.13 as 11.4.3.14;
0
i. Adding new section 11.4.3.13;
0
j. Re-designating section 11.4.4 as 11.4.13;
0
k. Adding sections: 11.4.4 introductory text; 11.4.4.1 through 
11.4.4.7; 11.4.5 introductory text; 11.4.5.1; 11.4.5.1.1 through 
11.4.5.1.9; 11.4.5.2 introductory text; 11.4.5.2.1 through 11.4.5.2.6; 
11.4.6 introductory text; 11.4.6.1 through 11.4.6.8, 11.4.7 
introductory text; 11.4.7.1 through 11.4.7.6; 11.4.8 introductory text; 
11.4.8.1 through 11.4.8.15; 11.4.9 introductory text; 11.4.9.1 through 
11.4.9.5; 11.4.10 introductory text; 11.4.10.1 through 11.4.10.8; 
11.4.11 introductory text; 11.4.11.1 through 11.4.11.7; 11.4.12 
introductory text; 11.4.12.1 through 11.4.12.9; and 11.4.13; and 
revising section 11.5.1.
    The revisions and additions read as follows:

Appendix B to Subpart UUUUU of Part 63--HCL and HF 
Monitoring Provisions

* * * * *

2. Monitoring of HCL and/or HF Emissions

* * * * *
    2.3 Monitoring System Equipment, Supplies, Definitions, and 
General Operation.
    The following provisions apply:
* * * * *

9. Data Reduction and Calculations

* * * * *
    9.4 Use Equation A-5 in appendix A of this subpart to calculate 
the required 30-boiler operating day rolling average HCl or HF 
emission rates. Report each 30-boiler operating day rolling average 
to the same precision as the standard (i.e., with one leading non-
zero digit and one decimal place), expressed in scientific notation. 
The term Eho in Equation A-5 must be in the units of the 
applicable emissions limit.
* * * * *

10. Recordkeeping Requirements

* * * * *
    10.1.3.3 The pollutant concentration, for each hour in which a 
quality-assured value is obtained. For HCl and HF, record the data 
in parts per million (ppm), with one leading non-zero digit and one 
decimal place, expressed in scientific notation. Use the following 
rounding convention: If the digit immediately following the first 
decimal place is 5 or greater, round the first decimal place upward 
(increase it by one); if the digit immediately following the first 
decimal place is 4 or less, leave the first decimal place unchanged.
* * * * *
    10.1.7.2 The hourly HCl and/or HF emissions rate (lb/MMBtu, or 
lb/MWh, as applicable), for each hour in which valid values of HCl 
or HF concentration and all other required parameters (stack gas 
volumetric flow rate, diluent gas concentration, electrical load, 
and moisture data, as applicable) are obtained for the hour. Round 
off the emission rate to the same precision as the standard (i.e., 
with one leading non-zero digit and one decimal place, expressed in 
scientific notation). Use the following rounding convention: If the 
digit immediately following the first decimal place is 5 or greater, 
round the first decimal place upward (increase it by one); if the 
digit immediately following the first decimal place is 4 or less, 
leave the first decimal place unchanged;
* * * * *
    10.1.8.1.1 For each required 7-day and daily calibration drift 
test or daily calibration error test (including daily calibration 
transfer standard tests) of the HCl or HF CEMS, record the test 
date(s) and time(s), reference gas value(s), monitor response(s), 
and calculated calibration drift or calibration error value(s). If 
you use the dynamic spiking option for the mid-level calibration 
drift check under PS-18, you must also record the measured 
concentration of the native HCl in the flue gas before and after the 
spike and the spiked gas dilution factor. When using an IP-CEMS 
under PS-18, you must also record the measured concentrations of the 
native HCl before and after introduction of each reference gas, the 
path lengths of the calibration cell and the stack optical path, the 
stack and calibration cell temperatures, the instrument line 
strength factor, and the calculated equivalent concentration of 
reference gas.
    10.1.8.1.2 For the required gas audits of an FTIR HCl or HF CEMS 
that is following PS 15, record the date and time of each spiked and 
unspiked sample, the audit gas reference values and uncertainties. 
Keep records of all calculations and data analyses required under 
sections 9.1 and 12.1 of Performance Specification 15, and the 
results of those calculations and analyses.
    10.1.8.1.3 For each required RATA of an HCl or HF CEMS, record 
the beginning and ending date and time of each test run, the 
reference method(s) used, and the reference method and HCl or HF 
CEMS run values. Keep records of stratification tests performed (if 
any), all of the raw field data, relevant process operating data, 
and all of the calculations used to determine the relative accuracy.
    10.1.8.1.4 For each required beam intensity test of an HCl IP-
CEMS under PS-18, record the test date and time, the known 
attenuation value (%) used for the test, the concentration of the 
high-level reference gas used, the full-beam and attenuated beam 
intensity levels, the measured HCl concentrations at full-beam 
intensity and attenuated intensity and the percent difference 
between them, and the results of the test. For each required daily 
beam intensity check of an IP-CEMS under Procedure 6, record the 
beam intensity measured including the units of measure and the 
results of the check.
    10.1.8.1.5 For each required measurement error (ME) test of an 
HCl monitor, record the date and time of each gas injection, the 
reference gas concentration (low, mid, or high) and the monitor 
response for each of the three injections at each of the three 
levels. Also record the average monitor response and the ME at each 
gas level and the related calculations. For ME tests conducted on 
IP-CEMS, also record the measured concentrations of the native HCl 
before and after introduction of each reference gas, the path 
lengths of the calibration cell and the stack optical path, the 
stack and calibration cell temperatures, the stack and calibration 
cell pressures, the instrument line strength factor, and the 
calculated equivalent concentration of reference gas.
    10.1.8.1.6 For each required level of detection (LOD) test of an 
HCl monitor performed in a controlled environment, record the test 
date, the concentrations of the reference gas and interference 
gases, the results of the seven (or more) consecutive measurements 
of HCl, the standard deviation, and the LOD value. For each required 
LOD test performed in the field, record the test date, the three 
measurements of the native source HCl concentration, the results of 
the three independent standard addition (SA) measurements known as 
standard addition response (SAR), the effective spike addition gas 
concentration (for IP-CEMS, the equivalent concentration of the 
reference gas), the resulting standard addition detection level 
(SADL) value and all related calculations. For extractive CEMS 
performing the SA using dynamic spiking, you must record the spiked 
gas dilution factor.
    10.1.8.1.7 For each required ME/level of detection response time 
test of an HCl monitor, record the test date, the native HCl 
concentration of the flue gas, the reference gas value, the stable 
reference gas readings, the upscale/downscale start and end times, 
and the results of the upscale and downscale stages of the test.
    10.1.8.1.8 For each required temperature or pressure measurement 
verification or audit of an IP-CEMS, keep records of the test date, 
the temperatures or pressures (as applicable) measured by the 
calibrated temperature or pressure reference device and the IP-CEMS, 
and the results of the test.
    10.1.8.1.9 For each required interference test of an HCl 
monitor, record (or obtain from the analyzer manufacturer records 
of): The date of the test; the gas volume/rate, temperature, and 
pressure used to conduct the test; the HCl concentration of the 
reference gas used; the concentrations of the interference test 
gases; the baseline HCl and HCl responses for each interferent 
combination spiked; and the total percent interference as a function 
of span or HCl concentration.
    10.1.8.1.10 For each quarterly relative accuracy audit (RAA) of 
an HCl monitor, record the beginning and ending date and time of 
each test run, the reference method

[[Page 55768]]

used, the HCl concentrations measured by the reference method and 
CEMS for each test run, the average concentrations measured by the 
reference method and the CEMS, and the calculated relative accuracy. 
Keep records of the raw field data, relevant process operating data, 
and the calculations used to determine the relative accuracy.
    10.1.8.1.11 For each quarterly cylinder gas audit (CGA) of an 
HCl monitor, record the date and time of each injection, and the 
reference gas concentration (zero, mid, or high) and the monitor 
response for each injection. Also record the average monitor 
response and the calculated ME at each gas level. For IP-CEMS, you 
must also record the measured concentrations of the native HCl 
before and after introduction of each reference gas, the path 
lengths of the calibration cell and the stack optical path, the 
stack and calibration cell temperatures, the stack and calibration 
cell pressures, the instrument line strength factor, and the 
calculated equivalent concentration of reference gas.
    10.1.8.1.12 For each quarterly dynamic spiking audit (DSA) of an 
HCl monitor, record the date and time of the zero gas injection and 
each spike injection, the results of the zero gas injection, the gas 
concentrations (mid and high) and the dilution factors and the 
monitor response for each of the six upscale injections as well as 
the corresponding native HCl concentrations measured before and 
after each injection. Also record the average dynamic spiking error 
for each of the upscale gases, the calculated average DSA Accuracy 
at each upscale gas concentration, and all calculations leading to 
the DSA Accuracy.
* * * * *

11. Reporting Requirements

* * * * *
    11.3.1 For an EGU that begins reporting hourly HCl and/or HF 
concentrations with a previously-certified CEMS, submit the 
monitoring plan information in section 10.1.1.2 of this appendix 
prior to or concurrent with the first required quarterly emissions 
report. For a new EGU, or for an EGU switching to continuous 
monitoring of HCl and/or HF emissions after having implemented 
another allowable compliance option under this subpart, submit the 
information in section 10.1.1.2 of this appendix at least 21 days 
prior to the start of initial certification testing of the CEMS. 
Also submit the monitoring plan information in section 75.53(g) 
pertaining to any required flow rate, diluent gas, and moisture 
monitoring systems within the applicable time frame specified in 
this section, if the required records are not already in place.
* * * * *
    11.4 Certification, Recertification, and Quality-Assurance Test 
Reporting Requirements. Except for daily QA tests (i.e., 
calibrations and flow monitor interference checks), which are 
included in each electronic quarterly emissions report, use the 
ECMPS Client Tool to submit the results of all required 
certification, recertification, quality-assurance, and diagnostic 
tests of the monitoring systems required under this appendix 
electronically. Submit the test results either prior to or 
concurrent with the relevant quarterly electronic emissions report. 
However, for RATAs of the HCl monitor, if this is not possible, you 
have up to 60 days after the test completion date to submit the test 
results; in this case, you may claim provisional status for the 
emissions data affected by the test, starting from the date and hour 
in which the test was completed and continuing until the date and 
hour in which the test results are submitted. If the test is 
successful, the status of the data in that time period changes from 
provisional to quality-assured, and no further action is required. 
However, if the test is unsuccessful, the provisional data must be 
invalidated and resubmission of the affected emission report(s) is 
required.
    11.4.1 For each daily calibration drift (or calibration error) 
assessment (including daily calibration transfer standard tests), 
and for each 7-day calibration drift test of an HCl or HF monitor, 
report:
    11.4.1.1 Facility ID information;
    11.4.1.2 The monitoring component ID;
    11.4.1.3 The instrument span and span scale;
    11.4.1.4 For each gas injection, the date and time, the 
calibration gas level (zero, mid or other), the reference gas value 
(ppm), and the monitor response (ppm);
    11.4.1.5 A flag to indicate whether dynamic spiking was used for 
the upscale value (extractive HCl monitors only);
    11.4.1.6 Calibration drift or calibration error (percent of span 
or reference gas, as applicable);
    11.4.1.7 When using the dynamic spiking option, the measured 
concentration of native HCl before and after each mid-level spike 
and the spiked gas dilution factor;
    11.4.1.8 When using an IP-CEMS, also report the measured 
concentration of native HCl before and after each upscale 
measurement, the path lengths of the calibration cell and the stack 
optical path, the stack and calibration cell temperatures, the stack 
and calibration cell pressures, the instrument line strength factor, 
and the equivalent concentration of the reference gas; and
    11.4.1.9 Reason for test (for the 7-day CD test, only).
    11.4.2 For each quarterly gas audit of an HCl or HF CEMS that is 
following PS 15, report:
* * * * *
    11.4.3.11 Standard deviation, using either Equation 2-4 in 
section 12.3 of PS 2 in appendix B to part 60 of this chapter or 
Equation 10 in section 12.6.5 of PS 18;
    11.4.3.12 Confidence coefficient, using either Equation 2-5 in 
section 12.4 of PS 2 in appendix B to part 60 of this chapter or 
Equation 11 in section 12.6.6 of PS 18;
    11.4.3.13 t-value; and
    11.4.3.14 Relative Accuracy. For FTIR monitoring systems 
following PS 15, calculate the relative accuracy using Equation 2-6 
of PS 2 in appendix B to part 60 of this chapter or, if applicable, 
according to the alternative procedure for low emitters described in 
section 3.1.2.2 of this appendix. For HCl CEMS following PS 18, 
calculate the relative accuracy according to section 12.6 of PS 18. 
If applicable use a flag to indicate that the alternative relative 
accuracy specification for low emitters has been applied.
    11.4.4 For each 3-level ME test of an HCl monitor, report:
    11.4.4.1 Facility ID information;
    11.4.4.2 Monitoring component ID;
    11.4.4.3 Instrument span and span scale;
    11.4.4.4 For each gas injection, the date and time, the 
calibration gas level (low, mid, or high), the reference gas value 
in ppm and the monitor response. When using an IP-CEMS, also report 
the measured concentration of native HCl before and after each 
injection, the path lengths of the calibration cell and the stack 
optical path, the stack and calibration cell temperatures, the stack 
and calibration cell pressures, the instrument line strength factor, 
and the equivalent concentration of the reference gas;
    11.4.4.5 For extractive CEMS, the mean reference value and mean 
of measured values at each reference gas level (ppm). For IP-CEMS, 
the mean of the measured concentration minus the average measured 
native concentration minus the equivalent reference gas 
concentration (ppm), at each reference gas level--see Equation 6A in 
PS 18;
    11.4.4.6 ME at each reference gas level; and
    11.4.4.7 Reason for test.
    11.4.5 Beam intensity tests of an IP CEMS:
    11.4.5.1 For the initial beam intensity test described in PS 18 
in appendix B to part 60 of this chapter, report:
    11.4.5.1.1 Facility ID information;
    11.4.5.1.2 Date and time of the test;
    11.4.5.1.3 Monitoring system ID;
    11.4.5.1.4 Reason for test;
    11.4.5.1.5 Attenuation value (%);
    11.4.5.1.6 High level gas concentration (ppm);
    11.4.5.1.7 Full and attenuated beam intensity levels, including 
units of measure;
    11.4.5.1.8 Measured HCl concentrations at full and attenuated 
beam intensity (ppm); and
    11.4.5.1.9 Percentage difference between the HCl concentrations.
    11.4.5.2 For the daily beam intensity check described in 
Procedure 6 of appendix F to Part 60 of this chapter, report:
    11.4.5.2.1 Facility ID information;
    11.4.5.2.2 Date and time of the test;
    11.4.5.2.3 Monitoring system ID;
    11.4.5.2.4 The attenuated beam intensity level (limit) 
established in the initial test;
    11.4.5.2.5 The beam intensity measured during the daily check; 
and
    11.4.5.2.6 Results of the test (pass or fail).
    11.4.6 For each temperature or pressure verification or audit of 
an HCl IP-CEMS, report:
    11.4.6.1 Facility ID information;
    11.4.6.2 Date and time of the test;
    11.4.6.3 Monitoring system ID;
    11.4.6.4 Type of verification (temperature or pressure);
    11.4.6.5 Stack sensor measured value;
    11.4.6.6 Reference device measured value;
    11.4.6.7 Results of the test (pass or fail); and
    11.4.6.8 Reason for test.
    11.4.7 For each interference test of an HCl monitoring system, 
report:

[[Page 55769]]

    11.4.7.1 Facility ID information;
    11.4.7.2 Date of test;
    11.4.7.3 Monitoring system ID;
    11.4.7.4 Results of the test (pass or fail);
    11.4.7.5 Reason for test; and
    11.4.7.6 A flag to indicate whether the test was performed: On 
this particular monitoring system; on one of multiple systems of the 
same type; or by the manufacturer on a system with components of the 
same make and model(s) as this system.
    11.4.8 For each LOD test of an HCl monitor, report:
    11.4.8.1 Facility ID information;
    11.4.8.2 Date of test;
    11.4.8.3 Reason for test;
    11.4.8.4 Monitoring system ID;
    11.4.8.5 A code to indicate whether the test was done in a 
controlled environment or in the field;
    11.4.8.6 HCl reference gas concentration;
    11.4.8.7 HCl responses with interference gas (seven 
repetitions);
    11.4.8.8 Standard deviation of HCl responses;
    11.4.8.9 Effective spike addition gas concentrations;
    11.4.8.10 HCl concentration measured without spike;
    11.4.8.11 HCl concentration measured with spike;
    11.4.8.12 Dilution factor for spike;
    11.4.8.13 The controlled environment LOD value (ppm or ppm-
meters);
    11.4.8.14 The field determined standard addition detection level 
(SADL in ppm or ppm-meters); and
    11.4.8.15 Result of LDO/SADL test (pass/fail).
    11.4.9 For each ME or LOD response time test of an HCl monitor, 
report:
    11.4.9.1 Facility ID information;
    11.4.9.2 Date of test;
    11.4.9.3 Monitoring component ID;
    11.4.9.4 The higher of the upscale or downscale tests, in 
minutes; and
    11.4.9.5 Reason for test.
    11.4.10 For each quarterly RAA of an HCl monitor, report:
    11.4.10.1 Facility ID information;
    11.4.10.2 Monitoring system ID;
    11.4.10.3 Begin and end time of each test run;
    11.4.10.4 The reference method used;
    11.4.10.5 The reference method and CEMS values for each test 
run, including the units of measure;
    11.4.10.6 The mean reference method and CEMS values for the 
three test runs;
    11.4.10.7 The calculated relative accuracy, percent; and
    11.4.10.8 Reason for test.
    11.4.11 For each quarterly cylinder gas audit of an HCl monitor, 
report:
    11.4.11.1 Facility ID information;
    11.4.11.2 Monitoring component ID;
    11.4.11.3 Instrument span and span scale;
    11.4.11.4 For each gas injection, the date and time, the 
reference gas level (zero, mid, or high), the reference gas value in 
ppm, and the monitor response. When using an IP-CEMS, also report 
the measured concentration of native HCl before and after each 
injection, the path lengths of the calibration cell and the stack 
optical path, the stack and calibration cell temperatures, the stack 
and calibration cell pressures, the instrument line strength factor, 
and the equivalent concentration of the reference gas;
    11.4.11.5 For extractive CEMS, the mean reference gas value and 
mean monitor response at each reference gas level (ppm). For IP-
CEMS, the mean of the measured concentration minus the average 
measured native concentration minus the equivalent reference gas 
concentration (ppm), at each reference gas level -see Equation 6A in 
PS 18;
    11.4.11.6 ME at each reference gas level; and
    11.4.11.7 Reason for test.
    11.4.12 For each quarterly DSA of an HCl monitor, report:
    11.4.12.1 Facility ID information;
    11.4.12.2 Monitoring component ID;
    11.4.12.3 Instrument span and span scale;
    11.4.12.4 For the zero gas injection, the date and time, and the 
monitor response (Note: The zero gas injection from a calibration 
drift check performed on the same day as the upscale spikes may be 
used for this purpose.);
    11.4.12.5 Zero spike error;
    11.4.12.6 For the upscale gas spiking, the date and time of each 
spike, the reference gas level (mid- or high-), the reference gas 
value (ppm), the dilution factor, the native HCl concentrations 
before and after each spike, and the monitor response for each gas 
spike;
    11.4.12.7 Upscale spike error;
    11.4.12.8 DSA at the zero level and at each upscale gas level; 
and
    11.4.12.9 Reason for test.
    11.4.13 Reporting Requirements for Diluent Gas, Flow Rate, and 
Moisture Monitoring Systems. For the certification, recertification, 
diagnostic, and QA tests of stack gas flow rate, moisture, and 
diluent gas monitoring systems that are certified and quality-
assured according to part 75 of this chapter, report the information 
in section 10.1.8.2 of this appendix.
* * * * *
    11.5.1 The owner or operator of any affected unit shall use the 
ECMPS Client Tool to submit electronic quarterly reports to the 
Administrator in an XML format specified by the Administrator, for 
each affected unit (or group of units monitored at a common stack). 
If the certified HCl or HF CEMS is used for the initial compliance 
demonstration, HCl or HF emissions reporting shall begin with the 
first operating hour of the 30-boiler operating day compliance 
demonstration period. Otherwise, HCl or HF emissions reporting shall 
begin with the first operating hour after successfully completing 
all required certification tests of the CEMS.
* * * * *

0
18. Subpart UUUUU of part 63 is amended by adding appendix C to read as 
follows:

Appendix C to Subpart UUUUU of Part 63--PM Monitoring Provisions

1. General Provisions

    1.1 Applicability. These monitoring provisions apply to the 
continuous measurement of filterable PM emissions from affected EGUs 
under this subpart. A PM CEMS is used together with other CMS and 
(as applicable) parametric measurement devices to quantify PM 
emissions in units of the applicable standard (i.e., lb/MMBtu or lb/
MWh).
    1.2 Initial Certification and Recertification Procedures.
    You, as the owner or operator of an affected EGU that uses a PM 
CEMS to demonstrate compliance with a filterable PM emissions limit 
in Table 1 or 2 to this subpart must certify and, if applicable, 
recertify the CEMS according to PS-11 in appendix B to part 60 of 
this chapter.
    1.3 Quality Assurance and Quality Control Requirements. You must 
meet the applicable quality assurance requirements of Procedure 2 in 
appendix F to part 60 of this chapter.
    1.4 Missing Data Procedures. You must not substitute data for 
missing data from the PM CEMS. Any process operating hour for which 
quality-assured PM concentration data are not obtained is counted as 
an hour of monitoring system downtime.
    1.5 Adjustments for Flow System Bias. When the PM emission rate 
is reported on a gross output basis, you must not adjust the data 
recorded by a stack gas flow rate monitor for bias, which may 
otherwise be required under section 75.24 of this chapter.

2. Monitoring of PM Emissions

    2.1 Monitoring System Installation Requirements. Flue gases from 
the affected EGUs under this subpart vent to the atmosphere through 
a variety of exhaust configurations including single stacks, common 
stack configurations, and multiple stack configurations. For each of 
these configurations, 40 CFR 63.10010(a) specifies the appropriate 
location(s) at which to install CMS. These CMS installation 
provisions apply to the PM CEMS and to the other CMS and parametric 
monitoring devices that provide data for the PM emissions 
calculations in section 6 of this appendix.
    2.2 Primary and Backup Monitoring Systems. In the electronic 
monitoring plan described in section 7 of this appendix, you must 
create and designate a primary monitoring system for PM and for each 
additional parameter (i.e., stack gas flow rate, CO2 or 
O2 concentration, stack gas moisture content, as 
applicable). The primary system must be used to report hourly PM 
concentration values when the system is able to provide quality-
assured data, i.e., when the system is ``in control.'' However, to 
increase data availability in the event of a primary monitoring 
system outage, you may install, operate, maintain, and calibrate a 
redundant backup monitoring system. A redundant backup system is one 
that is permanently installed at the unit or stack location and is 
kept on ``hot standby'' in case the primary monitoring system is 
unable to provide quality-assured data. You must represent each 
redundant backup system as a unique monitoring system in the 
electronic monitoring plan. You must certify each redundant backup 
monitoring system according to the applicable provisions in section 
4 of this appendix. In addition, each redundant monitoring system 
must meet the applicable on-going QA requirements in section 5 of 
this appendix.

[[Page 55770]]

3. PM Emissions Measurement Methods

    The following definitions, equipment specifications, procedures, 
and performance criteria are applicable
    3.1 Definitions. All definitions specified in section 3 of PS-11 
in appendix B to part 60 of this chapter and section 3 of Procedure 
2 in appendix F to part 60 of this chapter are applicable to the 
measurement of filterable PM emissions from electric utility steam 
generating units under this subpart. In addition, the following 
definitions apply:
    3.1.1 Stack operating hour means a clock hour during which flue 
gases flow through a particular stack or duct (either for the entire 
hour or for part of the hour) while the associated unit(s) are 
combusting fuel.
    3.1.2 Unit operating hour means a clock hour during which a unit 
combusts any fuel, either for part of the hour or for the entire 
hour.
    3.2 Continuous Monitoring Methods.
    3.2.1 Installation and Measurement Location. You must install 
the PM CEMS according to 40 CFR 63.10010 and Section 2.4 of PS-11.
    3.2.2 Units of Measure. For the purposes of this subpart, you 
shall report hourly PM concentrations in units of measure that 
correspond to your PM CEMS correlation curve (e.g., mg/acm, mg/acm @ 
160 [deg]C, mg/wscm, mg/dscm).
    3.2.3 Other Necessary Data Collection. To convert hourly PM 
concentrations to the units of the applicable emissions standard 
(i.e., lb/MMBtu or lb/MWh), you must collect additional data as 
described in sections 3.2.3.1 and 3.2.3.2 of this appendix. You must 
install, certify, operate, maintain, and quality-assure any stack 
gas flow rate, CO2, O2, or moisture monitoring 
systems needed for this purpose according to sections 4 and 5 of 
this appendix. The calculation methods for the emission limits 
described in sections 3.2.3.1 and 3.2.3.2 of this appendix are 
presented in section 6 of this appendix.
    3.2.3.1 Heat Input-Based Emission Limits. To demonstrate 
compliance with a heat input-based PM emission limit in Table 2 to 
this subpart, you must provide the hourly stack gas CO2 
or O2 concentration, along with a fuel-specific 
Fc factor or dry-basis F-factor and (if applicable) the 
stack gas moisture content, in order to convert measured PM 
concentrations values to the units of the standard.
    3.2.3.2 Gross Output-Based Emission Limits. To demonstrate 
compliance with a gross output-based PM emission limit in Table 1 or 
Table 2 to this subpart, you must provide the hourly gross output in 
megawatts, along with data from a certified stack gas flow rate 
monitor and (if applicable) the stack gas moisture content, in order 
to convert measured PM concentrations values to units of the 
standard.

4. Certification and Recertification Requirements

    4.1 Certification Requirements. You must certify your PM CEMS 
and the other CMS used to determine compliance with the applicable 
emissions standard before the PM CEMS can be used to provide data 
under this subpart. Redundant backup monitoring systems (if used) 
are subject to the same certification requirements as the primary 
systems.
    4.1.1 PM CEMS. You must certify your PM CEMS according to PS-11 
in appendix B to part 60 of this chapter. A PM CEMS that has been 
installed and certified according to PS-11 as a result of another 
state or federal regulatory requirement or consent decree prior to 
the effective date of this subpart shall be considered certified for 
this subpart if you can demonstrate that your PM CEMS meets the PS-
11 acceptance criteria based on the applicable emission standard in 
this subpart.
    4.1.2 Flow Rate, Diluent Gas, and Moisture Monitoring Systems. 
You must certify the continuous monitoring systems that are needed 
to convert PM concentrations to units of the standard or (if 
applicable) to convert the measured PM concentrations from wet basis 
to dry basis or vice-versa (i.e., stack gas flow rate, diluent gas 
(CO2 or O2) concentration, or moisture 
monitoring systems), in accordance with the applicable provisions in 
section 75.20 of this chapter and appendix A to part 75 of this 
chapter.
    4.1.3 Other Parametric Measurement Devices. Any temperature or 
pressure measurement devices that are used to convert hourly PM 
concentrations to standard conditions must be installed, calibrated, 
maintained, and operated according to the manufacturers' 
instructions.
    4.2 Recertification.
    4.2.1 You must recertify your PM CEMS if it is either: moved to 
a different stack or duct; moved to a new location within the same 
stack or duct; modified or repaired in such a way that the existing 
correlation is altered or impacted; or replaced.
    4.2.2 The flow rate, diluent gas, and moisture monitoring 
systems that are used to convert PM concentration to units of the 
emission standard are subject to the recertification provisions in 
section 75.20(b) of this chapter.
    4.3 Development of a New or Revised Correlation Curve. You must 
develop a new or revised correlation curve if:
    4.3.1 An RCA is failed and the new or revised correlation is 
developed according to section 10.6 in Procedure 2 of appendix F to 
part 60 of this chapter; or
    4.3.2 The events described in paragraph (1) or (2) in section 
8.8 of PS-11 occur.

5. Ongoing Quality Assurance (QA) and Data Validation

    5.1 PM CEMS.
    5.1.1 Required QA Tests. Following initial certification, you 
must conduct periodic QA testing of each primary and (if applicable) 
redundant backup PM CEMS. The required QA tests and the PS that must 
be met are found in Procedure 2 of appendix F to part 60 of this 
chapter (Procedure 2). Except as otherwise provided in section 5.1.2 
of this appendix, the QA tests shall be done at the frequency 
specified in Procedure 2.
    5.1.2 RRA and RCA Test Frequencies.
    5.1.2.1 The test frequency for RRAs of the PM CEMS shall be 
annual, i.e., once every 4 calendar quarters. The RRA must either be 
performed within the fourth calendar quarter after the calendar 
quarter in which the previous RRA was completed or in a grace period 
(see section 5.1.3, below). When a required annual RRA is done 
within a grace period, the deadline for the next RRA is 4 calendar 
quarters after the quarter in which the RRA was originally due, 
rather than the calendar quarter in which the grace period test is 
completed.
    5.1.2.2 The test frequency for RCAs of the PM CEMS shall be 
triennial, i.e., once every 12 calendar quarters. If a required RCA 
is not completed within 12 calendar quarters after the calendar 
quarter in which the previous RCA was completed, it must be 
performed in a grace period immediately following the twelfth 
calendar quarter (see section 5.1.3, below). When an RCA is done in 
a grace period, the deadline for the next RCA shall be 12 calendar 
quarters after the calendar quarter in which the RCA was originally 
due, rather than the calendar quarter in which the grace period test 
is completed.
    5.1.2.3 Successive quarterly audits (i.e., ACAs and, if 
applicable, sample volume audits (SVAs)) shall be conducted at least 
60 days apart.
    5.1.3 Grace Period. A grace period is available, immediately 
following the end of the calendar quarter in which an RRA or RCA of 
the PM CEMS is due. The length of the grace period shall be the 
lesser of 720 EGU (or stack) operating hours or 1 calendar quarter.
    5.1.4 RCA and RRA Acceptability. The results of your RRA or RCA 
are considered acceptable provided that the criteria in section 
10.4(5) of Procedure 2 in appendix F to part 60 of this chapter are 
met for an RCA or section 10.4(6) of Procedure 2 in appendix F to 
part 60 of this chapter are met for an RRA.
    5.1.5 Data Validation. Your PM CEMS is considered to be out-of-
control, and you may not report data from it as quality-assured, 
when, for a required certification, recertification, or QA test, the 
applicable acceptance criterion (either in PS-11 in appendix B to 
part 60 of this chapter or Procedure 2 in appendix F to part 60 of 
this chapter) is not met. Further, data from your PM CEMS are 
considered out-of-control, and may not be used for reporting, when a 
required QA test is not performed on schedule or within an allotted 
grace period. When an out-of-control period occurs, you must perform 
the appropriate follow-up actions. For an out-of-control period 
triggered by a failed QA test, you must perform and pass the same 
type of test in order to end the out-of-control period. For a QA 
test that is not performed on time, data from the PM CEMS remain 
out-of-control until the required test has been performed and 
passed. You must count all out-of-control data periods of the PM 
CEMS as hours of monitoring system downtime.
    5.2 Stack Gas Flow Rate, Diluent Gas, and Moisture Monitoring 
Systems. The on-going QA test requirements and data validation 
criteria for the primary and (if applicable) redundant backup stack 
gas flow rate, diluent gas, and moisture monitoring systems are 
specified in appendix B to part 75 of this chapter.
    5.3 QA/QC Program Requirements. You must develop and implement a 
QA/QC program for the PM CEMS and the other equipment that is used 
to provide data under this subpart. You may store your QA/QC plan

[[Page 55771]]

electronically, provided that the information can be made available 
expeditiously in hard copy to auditors and inspectors.
    5.3.1 General Requirements.
    5.3.1.1 Preventive Maintenance. You must keep a written record 
of the procedures needed to maintain the PM CEMS and other equipment 
that is used to provide data under this subpart in proper operating 
condition, along with a schedule for those procedures. At a minimum, 
you must include all procedures specified by the manufacturers of 
the equipment and, if applicable, additional or alternate procedures 
developed for the equipment.
    5.3.1.2 Recordkeeping Requirements. You must keep a written 
record describing procedures that will be used to implement the 
recordkeeping and reporting requirements of this appendix.
    5.3.1.3 Maintenance Records. You must keep a record of all 
testing, maintenance, or repair activities performed on the PM CEMS, 
and other equipment used to provide data under this subpart in a 
location and format suitable for inspection. You may use a 
maintenance log for this purpose. You must maintain the following 
records for each system or device: The date, time, and description 
of any testing, adjustment, repair, replacement, or preventive 
maintenance action performed, and records of any corrective actions 
taken. Additionally, you must record any adjustment that may affect 
the ability of a monitoring system or measurement device to make 
accurate measurements, and you must keep a written explanation of 
the procedures used to make the adjustment(s).
    5.3.2 Specific Requirements for the PM CEMS.
    5.3.2.1 Daily, and Quarterly Quality Assurance Assessments. You 
must keep a written record of the procedures used for daily 
assessments of the PM CEMS. You must also keep records of the 
procedures used to perform quarterly ACA and (if applicable) SVA 
audits. You must document how the test results are calculated and 
evaluated.
    5.3.2.2 Monitoring System Adjustments. You must document how 
each component of the PM CEMS will be adjusted to provide correct 
responses after routine maintenance, repairs, or corrective actions.
    5.3.2.3 Correlation Tests, Annual and Triennial Audits. You must 
keep a written record of procedures used for the correlation 
test(s), annual RRAs, and triennial RCAs of the PM CEMS. You must 
document how the test results are calculated and evaluated.
    5.3.3 Specific Requirements for Diluent Gas, Stack Gas Flow 
Rate, and Moisture Monitoring Systems. The QA/QC program 
requirements for the stack gas flow rate, diluent gas, and moisture 
monitoring systems described in section 3.2.3 of this appendix are 
specified in section 1 of appendix B to part 75 of this chapter.
    5.3.4 Requirements for Other Monitoring Equipment. For the 
equipment required to convert readings from the PM CEMS to standard 
conditions (e.g., devices to measure temperature and pressure), you 
must keep a written record of the calibrations and/or other 
procedures used to ensure that the devices provide accurate data.
    5.3.5 You may store your QA/QC plan electronically, provided 
that you can make the information available expeditiously in hard 
copy to auditors or inspectors.

6. Data Reduction and Caculations

    6.1 Data Reduction and Validation.
    6.1.1 You must reduce the data from PM CEMS to hourly averages, 
in accordance with 40 CFR 60.13(h)(2) of this chapter.
    6.1.2 You must reduce all CEMS data from stack gas flow rate, 
CO2, O2, and moisture monitoring systems to 
hourly averages according to 40 CFR 75.10(d)(1) of this chapter.
    6.1.3 You must reduce all other data from devices used to 
convert readings from the PM CEMS to standard conditions to hourly 
averages according to 40 CFR 60.13(h)(2) or 40 CFR 75.10(d)(1) of 
this chapter. This includes, but is not limited to, data from 
devices used to measure temperature and pressure, or, for 
cogeneration units that calculate gross output based on steam 
characteristics, devices to measure steam flow rate, steam pressure, 
and steam temperature.
    6.1.4 Do not calculate the PM emission rate for any unit or 
stack operating hour in which valid data are not obtained for PM 
concentration or for any parameter used in the PM emission rate 
calculations (i.e., gross output, stack gas flow rate, stack 
temperature, stack pressure, stack gas moisture content, or diluent 
gas concentration, as applicable).
    6.1.5 For the purposes of this appendix, part 75 substitute data 
values for stack gas flow rate, CO2 concentration, 
O2 concentration, and moisture content are not considered 
to be valid data.
    6.1.6 Operating hours in which PM concentration is missing or 
invalid are hours of monitoring system downtime. The use of 
substitute data for PM concentration is not allowed.
    6.1.7 You must exclude all data obtained during a boiler startup 
or shutdown operating hour (as defined in 40 CFR 63.10042) from the 
determination of the 30-boiler operating day rolling average PM 
emission rates.
    6.2 Calculation of PM Emission Rates. Unless your PM CEMS is 
correlated to provide PM concentrations at standard conditions, you 
must use the calculation methods in sections 6.2.1 through 6.2.3 of 
this appendix to convert measured PM concentration values to units 
of the emission limit (lb/MMBtu or lb/MWh, as applicable).
    6.2.1 PM concentrations must be at standard conditions in order 
to convert them to units of the emissions limit. If your PM CEMS 
measures PM concentrations at standard conditions, proceed to 
section 6.2.2 or 6.2.3, below (as applicable). However, if your PM 
CEMS measures PM concentrations in units of mg/acm or mg/acm at a 
specified temperature (e.g., 160 [deg]C), you must first use one of 
the following equations to convert the hourly PM concentration 
values from actual to standard conditions:
[GRAPHIC] [TIFF OMITTED] TR09SE20.002

    or
    [GRAPHIC] [TIFF OMITTED] TR09SE20.003
    
Where:

Cstd = PM concentration at standard conditions
Ca = PM concentration at measurement conditions
Ts = Stack Temperature ([deg]F)
TCEMS = CEMS Measurement Temperature ([deg]F)
PCEMS = CEMS Measurement Pressure (in. Hg)
Ps = Stack Pressure (in. Hg)
Tstd = Standard Temperature (68 [deg]F)
Pstd = Standard Pressure (29.92 in. Hg).

6.2.2 Heat Input-Based PM Emission Rates (Existing EGUs, Only). 
Calculate the hourly heat input-based PM emission rates (if 
applicable), in units of lb/MMBtu, according to sections 6.2.2.1 and 
6.2.2.2 of this appendix.
6.2.2.1 You must select an appropriate emission rate equation from 
among Equations 19-1 through 19-9 in appendix A-7 to part 60 of this 
chapter to convert the hourly PM concentration values from section 
6.2.1 of this appendix to units of lb/MMBtu. Note that the EPA test 
Method 19 equations require the pollutant concentration to be 
expressed in units of lb/scf; therefore, you must first multiply the 
PM

[[Page 55772]]

concentration by 6.24 x 10-8 to convert it from mg/scm to 
lb/scf.
    6.2.2.2 You must use the appropriate carbon-based or dry-basis 
F-factor in the emission rate equation that you have selected. You 
may either use an F-factor from Table 19-2 of EPA test Method 19 in 
appendix A-7 to part 60 of this chapter or from section 3.3.5 or 
section 3.3.6 of appendix F to part 75 of this chapter.
    6.2.2.3 If the hourly average O2 concentration is 
above 14.0% O2 (19.0% for an IGCC) or the hourly average 
CO2 concentration is below 5.0% CO2 (1.0% for 
an IGCC), you may calculate the PM emission rate using the 
applicable diluent cap value (as defined in 40 CFR 63.10042 and 
specified in 40 CFR 63.10007(f)(1)), provided that the diluent gas 
monitor is operating and recording quality-assured data).
    6.2.2.4 If your selected EPA test Method 19 equation requires a 
correction for the stack gas moisture content, you may either use 
quality-assured hourly data from a certified part 75 moisture 
monitoring system, a fuel-specific default moisture value from 40 
CFR 75.11(b) of this chapter, or a site-specific default moisture 
value approved by the Administrator under section 75.66 of this 
chapter.
    6.2.3 Gross Output-Based PM Emission Rates. For each unit or 
stack operating hour, if Cstd is measured on a wet basis, 
you must use Equation C-3 to calculate the gross output-based PM 
emission rate (if applicable). Use Equation C-4 if Cstd 
is measured on a dry basis:
[GRAPHIC] [TIFF OMITTED] TR09SE20.004

Where:

Eheo = Hourly gross output-based PM emission rate (lb/
MWh)
Cstd = PM concentration from section 6.2.1 (mg/scm), wet 
basis
Qs = Unadjusted stack gas volumetric flow rate (scfh, wet 
basis)
MW = Gross output (megawatts)
6.24 x 10-8 = Conversion factor
    or
    [GRAPHIC] [TIFF OMITTED] TR09SE20.005
    
Where:

Eheo = Hourly gross output-based PM emission rate (lb/
MWh)
Cstd = PM concentration from section 6.2.1 (mg/scm), dry 
basis
Qs = Unadjusted stack gas volumetric flow rate (scfh, wet 
basis)
MW = Gross output (megawatts)
Bws = Proportion by volume of water vapor in the stack 
gas
6.24 x 10-8 = Conversion factor

    6.2.4 You must calculate the 30-boiler operating day rolling 
average PM emission rates according to 40 CFR 63.10021(b).

7. Recordkeeping and Reporting

    7.1 Recordkeeping Provisions. For the PM CEMS and the other 
necessary CMS and parameter measurement devices installed at each 
affected unit or common stack, you must maintain a file of all 
measurements, data, reports, and other information required by this 
appendix in a form suitable for inspection, for 5 years from the 
date of each record, in accordance with 40 CFR 63.10033. The file 
shall contain the applicable information in sections 7.1.1 through 
7.1.11 of this appendix.
    7.1.1 Monitoring Plan Records. For each EGU or group of EGUs 
monitored at a common stack, you must prepare and maintain a 
monitoring plan for the PM CEMS and the other CMS(s) needed to 
convert PM concentrations to units of the applicable emission 
standard.
    7.1.1.1 Updates. If you make a replacement, modification, or 
change in a certified CEMS that is used to provide data under this 
appendix (including a change in the automated data acquisition and 
handling system (DAHS)) or if you make a change to the flue gas 
handling system and that replacement, modification, or change 
affects information reported in the monitoring plan (e.g., a change 
to a serial number for a component of a monitoring system), you 
shall update the monitoring plan.
    7.1.1.2 Contents of the Monitoring Plan. For the PM CEMS, your 
monitoring plan shall contain the applicable information in sections 
7.1.1.2.1 and 7.1.1.2.2 of this appendix. For required stack gas 
flow rate, diluent gas, and moisture monitoring systems, your 
monitoring plan shall include the applicable information required 
for those systems under 40 CFR 75.53 (g) and (h) of this chapter.
    7.1.1.2.1 Electronic. Your electronic monitoring plan records 
must include the following information: Unit or stack ID number(s); 
unit information (type of unit, maximum rated heat input, fuel 
type(s), emission controls); monitoring location(s); the monitoring 
methodologies used; monitoring system information, including (as 
applicable): Unique system and component ID numbers; the make, 
model, and serial number of the monitoring equipment; the sample 
acquisition method; formulas used to calculate emissions; operating 
range and load information; monitor span and range information; 
units of measure of your PM concentrations (see section 3.2.2); and 
appropriate default values. Your electronic monitoring plan shall be 
evaluated and submitted using the ECMPS Client Tool provided by the 
Clean Air Markets Division (CAMD) in EPA's Office of Atmospheric 
Programs.
    7.1.1.2.2 Hard Copy. You must keep records of the following 
items: Schematics and/or blueprints showing the location of the PM 
monitoring system(s) and test ports; data flow diagrams; test 
protocols; and miscellaneous technical justifications. The hard copy 
portion of the monitoring plan must also explain how the PM 
concentrations are measured and how they are converted to the units 
of the applicable emissions limit. The equation(s) used for the 
conversions must be documented. Electronic storage of the hard copy 
portion of the monitoring plan is permitted.
    7.1.2 Operating Parameter Records. You must record the following 
information for each operating hour of each EGU and also for each 
group of EGUs utilizing a monitored common stack, to the extent that 
these data are needed to convert PM concentration data to the units 
of the emission standard. For non-operating hours, you must record 
only the items in sections 7.1.2.1 and 7.1.2.2 of this appendix. If 
you elect to or are required to comply with a gross output-based PM 
standard, for any hour in which there is gross output greater than 
zero, you must record the items in sections 7.1.2.1 through 7.1.2.3 
and (if applicable) 7.1.2.5 of this appendix; however, if there is 
heat input to the unit(s) but no gross output (e.g., at unit 
startup), you must record the items in sections 7.1.2.1, 7.1.2.2, 
and, if applicable, section 7.1.2.5 of this appendix. If you elect 
to comply with a heat input-based PM standard, you must record only 
the items in sections 7.1.2.1, 7.1.2.2, 7.1.2.4, and, if applicable, 
section 7.1.2.5 of this appendix.
    7.1.2.1 The date and hour;
    7.1.2.2 The unit or stack operating time (rounded up to the 
nearest fraction of an hour (in equal increments that can range from 
1 hundredth to 1 quarter of an hour, at your option);
    7.1.2.3 The hourly gross output (rounded to nearest MWe);
    7.1.2.4 If applicable, the Fc factor or dry-basis F-
factor used to calculate the heat input-based PM emission rate; and
    7.1.2.5 If applicable, a flag to indicate that the hour is an 
exempt startup or shutdown hour.
    7.1.3 PM Concentration Records. For each affected unit or common 
stack using a PM CEMS, you must record the following

[[Page 55773]]

information for each unit or stack operating hour:
    7.1.3.1 The date and hour;
    7.1.3.2 Monitoring system and component identification codes for 
the PM CEMS, as provided in the electronic monitoring plan, if your 
CEMS provides a quality-assured value of PM concentration for the 
hour;
    7.1.3.3 The hourly PM concentration, in units of measure that 
correspond to your PM CEMS correlation curve, for each operating 
hour in which a quality-assured value is obtained. Record all PM 
concentrations with one leading non-zero digit and one decimal 
place, expressed in scientific notation. Use the following rounding 
convention: If the digit immediately following the first decimal 
place is 5 or greater, round the first decimal place upward 
(increase it by one); if the digit immediately following the first 
decimal place is 4 or less, leave the first decimal place unchanged.
    7.1.3.4 A special code, indicating whether or not a quality-
assured PM concentration is obtained for the hour; and
    7.1.3.5 Monitor data availability for PM concentration, as a 
percentage of unit or stack operating hours calculated in the manner 
established for SO2, CO2, O2 or 
moisture monitoring systems according to 40 CFR 75.32 of this 
chapter.
    7.1.4 Stack Gas Volumetric Flow Rate Records.
    7.1.4.1 When a gross output-based PM emissions limit must be 
met, in units of lb/MWh, you must obtain hourly measurements of 
stack gas volumetric flow rate during EGU operation, in order to 
convert PM concentrations to units of the standard.
    7.1.4.2 When hourly measurements of stack gas flow rate are 
needed, you must keep hourly records of the flow rates and related 
information, as specified in 40 CFR 75.57(c)(2) of this chapter.
    7.1.5 Records of Diluent Gas (CO2 or O2) 
Concentration.
    7.1.5.1 When a heat input-based PM emission limit must be met, 
in units of lb/MMBtu, you must obtain hourly measurements of 
CO2 or O2 concentration during EGU operation, 
in order to convert PM concentrations to units of the standard.
    7.1.5.2 When hourly measurements of diluent gas concentration 
are needed, you must keep hourly CO2 or O2 
concentration records, as specified in 40 CFR 75.57(g) of this 
chapter.
    7.1.6 Records of Stack Gas Moisture Content.
    7.1.6.1 When corrections for stack gas moisture content are 
needed to demonstrate compliance with the applicable PM emissions 
limit:
    7.1.6.1.1 If you use a continuous moisture monitoring system, 
you must keep hourly records of the stack gas moisture content and 
related information, as specified in 40 CFR 75.57(c)(3) of this 
chapter.
    7.1.6.1.2 If you use a fuel-specific default moisture value, you 
must represent it in the electronic monitoring plan required under 
section 7.1.1.2.1 of this appendix.
    7.1.7 PM Emission Rate Records. For applicable PM emission 
limits in units of lb/MMBtu or lb/MWh, you must record the following 
information for each affected EGU or common stack:
    7.1.7.1 The date and hour;
    7.1.7.2 The hourly PM emissions rate (lb/MMBtu or lb/MWh, as 
applicable), calculated according to section 6.2.2 or 6.2.3 of this 
appendix, rounded to the same precision as the standard (i.e., with 
one leading non-zero digit and one decimal place, expressed in 
scientific notation), expressed in scientific notation. Use the 
following rounding convention: If the digit immediately following 
the first decimal place is 5 or greater, round the first decimal 
place upward (increase it by one); if the digit immediately 
following the first decimal place is 4 or less, leave the first 
decimal place unchanged. You must calculate the PM emission rate 
only when valid values of PM concentration and all other required 
parameters required to convert PM concentration to the units of the 
standard are obtained for the hour;
    7.1.7.3 An identification code for the formula used to derive 
the hourly PM emission rate from measurements of the PM 
concentration and other necessary parameters (i.e., Equation C-3 or 
C-4 in section 6.2.3 of this appendix or the applicable EPA test 
Method 19 equation);
    7.1.7.4 If applicable, indicate that the diluent cap has been 
used to calculate the PM emission rate; and
    7.1.7.5 If applicable, indicate that the default electrical load 
(as defined in 40 CFR 63.10042) has been used to calculate the 
hourly PM emission rate.
    7.1.7.6 Indicate that the PM emission rate was not calculated 
for the hour, if valid data are not obtained for PM concentration 
and/or any of the other parameters in the PM emission rate equation. 
For the purposes of this appendix, substitute data values for stack 
gas flow rate, CO2 concentration, O2 
concentration, and moisture content reported under part 75 of this 
chapter are not considered to be valid data. However, when the gross 
output (as defined in 40 CFR 63.10042) is reported for an operating 
hour with zero output, the default electrical load value is treated 
as quality-assured data.
    7.1.8 Other Parametric Data. If your PM CEMS measures PM 
concentrations at actual conditions, you must keep records of the 
temperatures and pressures used in Equation C-1 or C-2 to convert 
the measured hourly PM concentrations to standard conditions.
    7.1.9 Certification, Recertification, and Quality Assurance Test 
Records. For any PM CEMS used to provide data under this subpart, 
you must record the following certification, recertification, and 
quality assurance information:
    7.1.9.1 The test dates and times, reference values, monitor 
responses, monitor full scale value, and calculated results for the 
required 7-day drift tests and for the required daily zero and 
upscale calibration drift tests;
    7.1.9.2 The test dates and times and results (pass or fail) of 
all daily system optics checks and daily sample volume checks of the 
PM CEMS (as applicable);
    7.1.9.3 The test dates and times, reference values, monitor 
responses, and calculated results for all required quarterly ACAs;
    7.1.9.4 The test dates and times, reference values, monitor 
responses, and calculated results for all required quarterly SVAs of 
extractive PM CEMS;
    7.1.9.5 The test dates and times, reference method readings and 
corresponding PM CEMS responses (including the units of measure), 
and the calculated results for all PM CEMS correlation tests, RRAs 
and RCAs. For the correlation tests, you must indicate which model 
is used (i.e., linear, logarithmic, exponential, polynomial, or 
power) and record the correlation equation. For the RRAs and RCAs, 
the reference method readings and PM CEMS responses must be reported 
in the same units of measure as the PM CEMS correlation;
    7.1.9.6 The cycle time and sample delay time for PM CEMS that 
operate in batch sampling mode; and
    7.1.9.7 Supporting information for all required PM CEMS 
correlation tests, RRAs, and RCAs, including records of all raw 
reference method and monitoring system data, the results of sample 
analyses to substantiate the reported test results, as well as 
records of sampling equipment calibrations, reference monitor 
calibrations, and analytical equipment calibrations.
    7.1.10 For stack gas flow rate, diluent gas, and moisture 
monitoring systems, you must keep records of all certification, 
recertification, diagnostic, and on-going quality-assurance tests of 
these systems, as specified in 40 CFR 75.59(a) of this chapter.
    7.1.11 For each temperature measurement device (e.g., resistance 
temperature detector or thermocouple) and pressure measurement 
device used to convert measured PM concentrations to standard 
conditions according to Equation C-1 or C-2, you must keep records 
of all calibrations and other checks performed to ensure that 
accurate data are obtained.
    7.2 Reporting Requirements.
    7.2.1 General Reporting Provisions. You must comply with the 
following requirements for reporting PM emissions from each affected 
EGU (or group of EGUs monitored at a common stack) under this 
subpart:
    7.2.1.1 Notifications, in accordance with section 7.2.2 of this 
appendix;
    7.2.1.2 Monitoring plan reporting, in accordance with section 
7.2.3 of this appendix;
    7.2.1.3 Certification, recertification, and quality assurance 
test submittals, in accordance with section 7.2.4 of this appendix; 
and
    7.2.1.4 Electronic quarterly emissions report submittals, in 
accordance with section 7.2.5 of this appendix.
    7.2.2 Notifications. You must provide notifications for each 
affected unit (or group of units monitored at a common stack) under 
this subpart in accordance with 40 CFR 63.10030.
    7.2.3 Monitoring Plan Reporting. For each affected unit (or 
group of units monitored at a common stack) under this subpart using 
PM CEMS to measure PM emissions, you must make electronic and hard 
copy monitoring plan submittals as follows:
    7.2.3.1 For an EGU that begins reporting hourly PM 
concentrations on January 1, 2024, with a previously certified PM 
CEMS, submit the monitoring plan information in

[[Page 55774]]

section 7.1.1.2 of this appendix prior to or concurrent with the 
first required quarterly emissions report. For a new EGU, or for an 
EGU switching to continuous monitoring of PM emissions after having 
implemented another allowable compliance option under this subpart, 
submit the information in section 7.1.1.2 of this appendix at least 
21 days prior to the start of initial certification testing of the 
PM CEMS. Also submit the monitoring plan information in 40 CFR 
75.53(g) pertaining to any required flow rate, diluent gas, and 
moisture monitoring systems within the applicable time frame 
specified in this section, if the required records are not already 
in place.
    7.2.3.2 Whenever an update of the monitoring plan is required, 
as provided in section 7.1.1.1 of this appendix, you must submit the 
updated information either prior to or concurrent with the relevant 
quarterly electronic emissions report.
    7.2.3.3 All electronic monitoring plan submittals and updates 
shall be made to the Administrator using the ECMPS Client Tool. Hard 
copy portions of the monitoring plan shall be submitted to the 
appropriate delegated authority.
    7.2.4 Certification, Recertification, and Quality-Assurance Test 
Reporting. Except for daily quality assurance tests of the required 
monitoring systems (i.e., calibration error or drift tests, sample 
volume checks, system optics checks, and flow monitor interference 
checks), you must submit the results of all required certification, 
recertification, and quality-assurance tests described in sections 
7.1.9.1 through 7.1.9.6 and 7.1.10 of this appendix electronically 
(except for test results previously submitted, e.g., under the Acid 
Rain Program), using the ECMPS Client Tool. Submit the results of 
the quality assurance test (i.e., RCA or RRA) or, if applicable, a 
new PM CEMS correlation test, either prior to or concurrent with the 
relevant quarterly electronic emissions report. If this is not 
possible, you have up to 60 days after the test completion date to 
submit the test results; in this case, you may claim provisional 
status for the emissions data affected by the quality assurance test 
or correlation, starting from the date and hour in which the test 
was completed and continuing until the date and hour in which the 
test results are submitted. For an RRA or RCA, if the applicable 
audit specifications are met, the status of the emissions data in 
the relevant time period changes from provisional to quality-
assured, and no further action is required. For a successful 
correlation test, apply the correlation equation retrospectively to 
the raw data to change the provisional status of the data to 
quality-assured, and resubmit the affected emissions report(s). 
However, if the applicable performance specifications are not met, 
the provisional data must be invalidated, and resubmission of the 
affected quarterly emission report(s) is required. For a failed RRA 
or RCA, you must take corrective actions and proceed according to 
the applicable requirements found in sections 10.5 through 10.7 of 
Procedure 2 until a successful quality assurance test report is 
submitted. If a correlation test is unsuccessful, you may not report 
quality-assured data from the PM CEMS until the results of a 
subsequent correlation test show that the specifications in section 
13.0 of PS 11 are met.
    7.2.5 Quarterly Reports.
    7.2.5.1 For each affected EGU (or group of EGUs monitored at a 
common stack), the owner or operator must use the ECMPS Client Tool 
to submit electronic quarterly emissions reports to the 
Administrator, in an XML format specified by the Administrator, 
starting with a report for the later of:
    7.2.5.1.1 The first calendar quarter of 2024; or
    7.2.5.1.2 The calendar quarter in which the initial PM CEMS 
correlation test is completed.
    7.2.5.2 You must submit the electronic reports within 30 days 
following the end of each calendar quarter, except for EGUs that 
have been placed in long-term cold storage (as defined in section 
72.2 of this chapter).
    7.2.5.3 Each of your electronic quarterly reports shall include 
the following information:
    7.2.5.3.1 The date of report generation;
    7.2.5.3.2 Facility identification information;
    7.2.5.3.3 The information in sections 7.1.2 through 7.1.7 of 
this appendix that is applicable to your PM emission measurement 
methodology; and
    7.2.5.3.4 The results of all daily quality assurance 
assessments, i.e., calibration drift checks and (if applicable) 
sample volume checks of the PM CEMS, calibration error tests of the 
other continuous monitoring systems that are used to convert PM 
concentration to units of the standard, and (if applicable) flow 
monitor interference checks.
    7.2.5.4 Compliance Certification. Based on a reasonable inquiry 
of those persons with primary responsibility for ensuring that all 
PM emissions from the affected unit(s) under this subpart have been 
correctly and fully monitored, the owner or operator must submit a 
compliance certification in support of each electronic quarterly 
emissions monitoring report. The compliance certification shall 
include a statement by a responsible official with that official's 
name, title, and signature, certifying that, to the best of his or 
her knowledge, the report is true, accurate, and complete.

0
19. Subpart UUUUU of part 63 is amended by adding appendix D, to read 
as follows:

Appendix D to SUBPART UUUUU of Part 63--PM CPMS Monitoring Provisions

1. General Provisions

    1.1 Applicability. These monitoring provisions apply to the 
continuous monitoring of the output from a PM CPMS, for the purpose 
of assessing continuous compliance with an applicable emissions 
limit in Table 1 or Table 2 to this subpart.
    1.2 Summary of the Method. The output from an instrument capable 
of continuously measuring PM concentration is continuously recorded, 
either in milliamps, PM concentration, or other units of measure. An 
operating limit for the PM CPMS is established initially, based on 
data recorded by the monitoring system during a performance stack 
test. The performance test is repeated annually, and the operating 
limit is reassessed. In-between successive performance tests, the 
output from the PM CPMS serves as an indicator of continuous 
compliance with the applicable emissions limit.

2. Continuous Monitoring of the PM CPMS Output

    2.1 System Design and Performance Criteria. The PM CPMS must 
meet the design and performance criteria specified in 40 CFR 
63.10010(h)(1)(i) through (iii) and 40 CFR 63.10023(b)(2)(iii) and 
(iv). In addition, an automated DAHS is required to record the 
output from the PM CPMS and to generate the quarterly electronic 
data reports required under section 3.2.4 of this appendix.
    2.2 Installation Requirements. Install the PM CPMS at an 
appropriate location in the stack or duct, in accordance with 40 CFR 
63.10010(a).
    2.3 Determination of Operating Limits.
    2.3.1 In accordance with 40 CFR 63.10007(a)(3), 40 CFR 
63.10011(b), 40 CFR 63.10023(a), and Table 6 to this subpart, you 
must determine an initial site-specific operating limit for your PM 
CPMS, using data recorded by the monitoring system during a 
performance stack test that demonstrates compliance with one of the 
following emissions limits in Table 1 or Table 2 to this subpart: 
Filterable PM; total non-Hg HAP metals; total HAP metals including 
Hg (liquid oil-fired units, only); individual non-Hg HAP metals; or 
individual HAP metals including Hg (liquid oil-fired units, only).
    2.3.2 In accordance with 40 CFR 63.10005(d)(2)(i), you must 
perform the initial stack test no later than the applicable date in 
40 CFR 63.9984(f), and according to 40 CFR 63.10005(d)(2)(iii) and 
63.10006(a), the performance test must be repeated annually to 
document compliance with the emissions limit and to reassess the 
operating limit.
    2.3.3 Calculate the operating limits according to 40 CFR 
63.10023(b)(1) for existing units, and 40 CFR 63.10023(b)(2) for new 
units.
    2.4 Data Reduction and Compliance Assessment.
    2.4.1 Reduce the output from the PM CPMS to hourly averages, in 
accordance with 40 CFR 63.8(g)(2) and (5).
    2.4.2 To determine continuous compliance with the operating 
limit, you must calculate 30-boiler operating day rolling average 
values of the output from the PM CPMS, in accordance with 40 CFR 
63.10010(h)(3) through (6), 40 CFR 63.10021(c), and Table 7 to this 
subpart.
    2.4.3 In accordance with 40 CFR 63.10005(d)(2)(ii), 40 CFR 
63.10022(a)(2), and Table 4 to this subpart, the 30-boiler operating 
day rolling average PM CPMS output must be maintained at or below 
the operating limit. However, if exceedances of the operating limit 
should occur, you must follow the applicable procedures in 40 CFR 
63.10021(c)(1) and (2).

3. RECORDKEEPING AND REPORTING.

    3.1 Recordkeeping Provisions. You must keep the applicable 
records required under

[[Page 55775]]

40 CFR 63.10032(b) and (c) for your PM CPMS. In addition, you must 
maintain a file of all measurements, data, reports, and other 
information required by this appendix in a form suitable for 
inspection, for 5 years from the date of each record, in accordance 
with 40 CFR 63.10033.
    3.1.1 Monitoring Plan Records.
    3.1.1.1 You must develop and maintain a site-specific monitoring 
plan for your PM CPMS, in accordance with 63.10000(d).
    3.1.1.2 In addition to the site-specific monitoring plan 
required under 40 CFR 63.10000(d), you must use the ECMPS Client 
Tool to prepare and maintain an electronic monitoring plan for your 
PM CPMS.
    3.1.1.2.1 Contents of the Electronic Monitoring Plan. The 
electronic monitoring plan records must include the unit or stack ID 
number(s), monitoring location(s), the monitoring methodology used 
(i.e., PM CPMS), the current operating limit of the PM CPMS 
(including the units of measure), unique system and component ID 
numbers, the make, model, and serial number of the PM CPMS, the 
analytical principle of the monitoring system, and monitor span and 
range information.
    3.1.1.2.2 Electronic Monitoring Plan Updates. If you replace or 
make a change to a PM CPMS that is used to provide data under this 
subpart (including a change in the automated DAHS) and the 
replacement or change affects information reported in the electronic 
monitoring plan (e.g., changes to the make, model and serial number 
when a PM CPMS is replaced), you must update the monitoring plan.
    3.1.2 Operating Parameter Records. You must record the following 
information for each operating hour of each affected unit and for 
each group of units utilizing a common stack. For non-operating 
hours, record only the items in sections 3.1.2.1 and 3.1.2.2 of this 
appendix.
    3.1.2.1 The date and hour;
    3.1.2.2 The unit or stack operating time (rounded up to the 
nearest fraction of an hour (in equal increments that can range from 
1 hundredth to 1 quarter of an hour, at the option of the owner or 
operator); and
    3.1.2.3 If applicable, a flag to indicate that the hour is an 
exempt startup or shutdown hour.
    3.1.3 PM CPMS Output Records. For each affected unit or common 
stack using a PM CPMS, you must record the following information for 
each unit or stack operating hour:
    3.1.3.1 The date and hour;
    3.1.3.2 Monitoring system and component identification codes for 
the PM CPMS, as provided in the electronic monitoring plan, for each 
operating hour in which the monitoring system is not out-of-control 
and a valid value of the output parameter is obtained;
    3.1.3.3 The hourly average output from the PM CPMS, for each 
operating hour in which the monitoring system is not out-of-control 
and a valid value of the output parameter is obtained, either in 
milliamps, PM concentration, or other units of measure, as 
applicable;
    3.1.3.4 A special code for each operating hour in which the PM 
CPMS is out-of-control and a valid value of the output parameter is 
not obtained; and
    3.1.3.5 Percent monitor data availability for the PM CPMS, 
calculated in the manner established for SO2, 
CO2, O2 or moisture monitoring systems 
according to section 75.32 of this chapter.
    3.1.4 Records of PM CPMS Audits and Out-of-Control Periods. In 
accordance with 40 CFR 63.10010(h)(7), you must record, and make 
available upon request, the results of PM CPMS performance audits, 
as well as the dates of PM CPMS out-of-control periods and the 
corrective actions taken to return the system to normal operation.
    3.2 Reporting Requirements.
    3.2.1 General Reporting Provisions. You must comply with the 
following requirements for reporting PM CPMS data from each affected 
EGU (or group of EGUs monitored at a common stack) under this 
subpart:
    3.2.1.1 Notifications, in accordance with section 3.2.2 of this 
appendix;
    3.2.1.2 Monitoring plan reporting, in accordance with section 
3.2.3 of this appendix;
    3.2.1.3 Report submittals, in accordance with sections 3.2.4 and 
3.2.5 of this appendix.
    3.2.2 Notifications. You must provide notifications for the 
affected unit (or group of units monitored at a common stack) in 
accordance with 40 CFR 63.10030.
    3.2.3 Monitoring Plan Reporting. For each affected unit (or 
group of units monitored at a common stack) under this subpart using 
a PM CPMS you must make monitoring plan submittals as follows:
    3.2.3.1 For units using the PM CPMS compliance option prior to 
January 1, 2024, submit the electronic monitoring plan information 
in section 3.1.1.2.1 of this appendix prior to or concurrent with 
the first required electronic quarterly report. For units switching 
to the PM CPMS methodology on or after January 1, 2024, submit the 
electronic monitoring plan no later than 21 days prior to the date 
on which the PM test is performed to establish the initial operating 
limit.
    3.2.3.2 Whenever an update of the electronic monitoring plan is 
required, as provided in section 3.1.1.2.2 of this appendix, the 
updated information must be submitted either prior to or concurrent 
with the relevant quarterly electronic emissions report.
    3.2.3.3 All electronic monitoring plan submittals and updates 
shall be made to the Administrator using the ECMPS Client Tool.
    3.2.3.4 In accordance with 40 CFR 63.10000(d), you must submit 
the site-specific monitoring plan described in section 3.1.1.1 of 
this appendix to the Administrator, if requested.
    3.2.4 Electronic Quarterly Reports.
    3.2.4.1 For each affected EGU (or group of EGUs monitored at a 
common stack) that is subject to the provisions of this appendix, 
reporting of hourly responses from the PM CPMS will begin either 
with the first operating hour in the third quarter of 2023 or the 
first operating hour after completion of the initial stack test that 
establishes the operating limit, whichever is later. The owner or 
operator must then use the ECMPS Client Tool to submit electronic 
quarterly reports to the Administrator, in an XML format specified 
by the Administrator, starting with a report for the later of:
    3.2.4.1.1 The first calendar quarter of 2024; or
    3.2.4.1.2 The calendar quarter in which the initial operating 
limit for the PM CPMS is established.
    3.2.4.2 The electronic quarterly reports must be submitted 
within 30 days following the end of each calendar quarter, except 
for units that have been placed in long-term cold storage (as 
defined in section 72.2 of this chapter).
    3.2.4.3 Each electronic quarterly report shall include the 
following information:
    3.2.4.3.1 The date of report generation;
    3.2.4.3.2 Facility identification information; and
    3.2.4.3.3 The information in sections 3.1.2 and 3.1.3 of this 
appendix.
    3.2.4.4 Compliance Certification. Based on a reasonable inquiry 
of those persons with primary responsibility for ensuring that the 
output from the PM CPMS has been correctly and fully monitored, the 
owner or operator shall submit a compliance certification in support 
of each electronic quarterly report. The compliance certification 
shall include a statement by a responsible official with that 
official's name, title, and signature, certifying that, to the best 
of his or her knowledge, the report is true, accurate, and complete.
    3.2.5 Performance Stack Test Results. You must use the ECMPS 
Client Tool to report the results of all performance stack tests 
conducted to document compliance with the applicable emissions limit 
in Table 1 or Table 2 to this subpart, as follows:
    3.2.5.1 Report a summary of each test electronically, in XML 
format, in the relevant quarterly compliance report under 40 CFR 
63.10031(g); and
    3.2.5.2 Provide a complete stack test report as a PDF file, in 
accordance with 40 CFR 63.10031(f) or (h), as applicable.

0
20. Subpart UUUUU of part 63 is amended by adding appendix E, to read 
as follows:

Appendix E to Subpart UUUUU of Part 63--Data Elements

    1.0 You must record the electronic data elements in this 
appendix that apply to your compliance strategy under this subpart. 
The applicable data elements in sections 2 through 13 of this 
appendix must be reported in the quarterly compliance reports 
required under 40 CFR 63.10031(g), in an XML format prescribed by 
the Administrator, starting with a report that covers the first 
quarter of 2024. For stack tests used to demonstrate compliance, 
RATAs, PM CEMS correlations, RRAs and RCAs that are completed on and 
after January 1, 2024, the applicable data elements in sections 17 
through 30 of this appendix must be reported in an XML format 
prescribed by the Administrator, and the information in section 31 
of this appendix must be reported in as one or more PDF files.
    2.0 MATS Compliance Report Root Data Elements. You must record 
the following data elements and include them in each quarterly 
compliance report:

[[Page 55776]]

    2.1 Energy Information Administration's Office of Regulatory 
Information Systems (ORIS) Code;
    2.2 Facility Name;
    2.3 Facility Registry Identifier;
    2.4 Title 40 Part;
    2.5 Applicable Subpart;
    2.6 Calendar Year;
    2.7 Calendar Quarter; and
    2.8 Submission Comment (optional)
    3.0 Performance Stack Test Summary. If you elect to demonstrate 
compliance using periodic performance stack testing (including 30-
boiler operating day Hg LEE tests), record the following data 
elements for each test:
    3.1 Parameter
    3.2 Test Location ID;
    3.3 Test Number;
    3.4 Test Begin Date, Hour, and Minute;
    3.5 Test End Date, Hour, and Minute;
    3.6 Timing of Test (either performed on-schedule according to 40 
CFR 63.10006(f), or was late);
    3.7 Averaging Plan Indicator;
    3.8 Averaging Group ID (if applicable);
    3.9 EPA Test Method Code;
    3.10 Emission Limit, Including Units of Measure;
    3.11 Average Pollutant Emission Rate;
    3.12 LEE Indicator;
    3.13 LEE Basis (if applicable); and
    3.14 Submission Comment (optional)
    4.0 Operating limit Data (PM CPMS, only):
    4.1 Parameter Type;
    4.2 Operating Limit; and
    4.3 Units of Measure.
    5.0 Performance Test Run Data. For each run of the performance 
stack test, record the following data elements:
    5.1 Run Number
    5.2 Run Begin Date, Hour, and Minute;
    5.3 Run End Date, Hour, and Minute;
    5.4 Pollutant Concentration and Units of Measure;
    5.5 Emission Rate;
    5.6 EPA Test Method 19 Equation (if applicable);
    5.7 Total Sampling Time; and
    5.8 Total Sample Volume.
    6.0 Conversion Parameters. For the parameters that are used to 
convert the pollutant concentration to units of the emission 
standard (including, as applicable, CO2 or O2 
concentration, stack gas flow rate, stack gas moisture content, F-
factors, and gross output), record:
    6.1 Parameter Type;
    6.2 Parameter Source; and
    6.3 Parameter Value, Including Units of Measure.
    7.0 Quality Assurance Parameters: For key parameters that are 
used to quality-assure the reference method data (including, as 
applicable, filter temperature, percent isokinetic, leak check 
results, percent breakthrough, percent spike recovery, and relative 
deviation), record:
    7.1 Parameter Type;
    7.2 Parameter Value; and
    7.3 Pass/Fail Status.
    8.0 Averaging Group Configuration. If a particular EGU or common 
stack is included in an averaging plan, record the following data 
elements:
    8.1 Parameter Being Averaged;
    8.2 Averaging Group ID; and
    8.3 Unit or Common Stack ID.
    9.0 Compliance Averages. If you elect to (or are required to) 
demonstrate compliance using continuous monitoring system(s) on a 
30-boiler operating day rolling average basis (or on a 30- or 90-
group boiler operating day rolling WAER basis, if your monitored EGU 
or common stack is in an averaging plan), you must record the 
following data elements for each average emission rate (or, for 
units in an averaging plan, for each WAER):
    9.1 Unit or Common Stack ID;
    9.2 Averaging Group ID (if applicable);
    9.3 Parameter Being Averaged;
    9.4 Date;
    9.5 Average Type;
    9.6 Units of Measure; and
    9.7 Average Value.
    9.8 Comment Field.
    10.0 Unit Information. You must record the following data 
elements for each EGU:
    10.1 Unit ID;
    10.2 Date of Last Tune-up; and
    10.3 Emergency Bypass Information. If your coal-fired EGU, solid 
oil-derived fuel-fired EGU, or IGCC is equipped with a main stack 
and a bypass stack (or bypass duct) configuration, and has qualified 
to use the LEE compliance option, you must report the following 
emergency bypass information annually, in the compliance report for 
the fourth calendar quarter of the year:
    10.3.1 The number of emergency bypass hours for the year, as a 
percentage of the EGU's annual operating hours;
    10.3.2 A description of each emergency bypass event during the 
year, including the cause and corrective actions taken;
    10.3.3 An explanation of how clean fuels were burned to the 
maximum extent possible during each emergency bypass event;
    10.3.4 An estimate of the emissions released during each 
emergency bypass event. You must also show whether LEE status has 
been retained or lost, based on the emissions estimate and the 
results of the previous LEE retest; and
    10.3.5 If there were no emergency bypass events during the year, 
a statement to that effect.
    11.0 Fuel Usage Information. If subject to an emissions limit, 
record the following monthly fuel usage information:
    11.1 Calendar Month;
    11.2 Each Type of Fuel Used During the Calendar Month in the 
Quarter;
    11.3 Quantity of Each Type of Fuel Combusted in Each Calendar 
Month in the Quarter, with Units of Measure;
    11.4 New Fuel Type Indicator (if applicable); and
    11.5 Date of Performance Test Using the New Fuel (if applicable.
    12.0 Malfunction Information (if applicable): If there was a 
malfunction of the process equipment or control equipment during the 
reporting period that caused (or may have caused) an exceedance of 
an emissions or operating limit, record:
    12.1 Event Begin Date and Hour (if known);
    12.2 Event End Date and Hour;
    12.3 Malfunction Description; and
    12.4 Corrective Action.
    13.0 Deviations and Monitoring Downtime. If there were any 
deviations or monitoring downtime during the reporting period, 
record:
    13.1 Unit, Common Stack, or Averaging Group ID;
    13.2 The nature of the deviation, as either:
    13.2.1 Emission limit exceeded;
    13.2.2 Operating limit exceeded;
    13.2.3 Work practice standard not met;
    13.2.4 Testing requirement not met;
    13.2.5 Monitoring requirement not met;
    13.2.6 Monitoring downtime incurred; or
    13.2.7 Other requirement not met.
    13.3 A description of the deviation, or monitoring downtime, as 
follows:
    13.3.1 For a performance stack test or a 30- (or 90-) boiler 
operating day rolling average that exceeds an emissions or operating 
limit, record the parameter (e.g., HCl, Hg, PM), the limit that was 
exceeded, and either the date of the non-complying performance test 
or the beginning and ending dates of the non-complying rolling 
average;
    13.3.2 If an unmonitored bypass stack was used during the 
reporting period, record the total number of hours of bypass stack 
usage;
    13.3.3 For periods where valid monitoring data are not reported 
during the reporting period, record the monitored parameter, the 
total source operating time (hours), and the total number of hours 
of monitoring deviation or downtime and other information, as 
indicated, for:
    13.3.3.1 Monitoring system malfunctions/repairs (deviation and 
downtime);
    13.3.3.2 Out-of-control periods/repairs (deviation and 
downtime);
    13.3.3.3 Non-monitoring equipment malfunctions (downtime);
    13.3.3.4 QA/QC activities (excluding zero and span checks) 
(downtime);
    13.3.3.5 Routine maintenance (downtime);
    13.3.3.6 Other known causes (downtime); and
    13.3.3.7 Unknown causes (downtime).
    13.3.4 If a performance stack test was due within the quarter 
but was not done, record the parameter (e.g., HCl, PM), the test 
deadline, and a statement that the test was not done as required;
    13.3.5 For a late performance stack test conducted during the 
quarter, record the parameter, the test deadline, and the number of 
days that elapsed between the test deadline and the test completion 
date.
    13.4 Record any corrective actions taken in response to the 
deviation.
    13.5 If there were no deviations and/or no monitoring downtime 
during the quarter, record a statement to that effect.
    14.0 Reference Method Data Elements. For each of the following 
tests that is completed on and after January 1, 2024, you must 
record and report the applicable electronic data elements in 
sections 17 through 29 of this appendix, pertaining to the reference 
method(s) used for the test (see section 16 of this appendix).
    14.1 Each quarterly, annual, or triennial stack test used to 
demonstrate compliance (including 30- (or 90-) boiler operating day 
Hg LEE tests and PM tests used to set operating limits for PM CPMS);

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    14.2 Each RATA of your Hg, HCl, HF, or SO2 CEMS or 
each RATA of your Hg sorbent trap monitoring system; and
    14.3 Each correlation test, RRA and each RCA of your PM CEMS.
    15.0 You must report the applicable data elements for each test 
described in section 14 of this appendix in an XML format prescribed 
by the Administrator.
    15.1 For each stack test completed during a particular calendar 
quarter and contained in the quarterly compliance report, you must 
submit along with the quarterly compliance report, the data elements 
in sections 17 and 18 of this appendix (which are common to all 
tests) and the applicable data elements in sections 19 through 31 of 
this appendix associated with the reference method(s) used.
    15.2 For each RATA, PM CEMS correlation, RRA, or RCA, when you 
use the ECMPS Client Tool to report the test results as required 
under appendix A, B, or C to this subpart or, for SO2 
RATAs under part 75 of this chapter, you must submit along with the 
test results, the data elements in sections 17 and 18 of this 
appendix and, for each test run, the data elements in sections 19 
through 30 of this appendix that are associated with the reference 
method(s) used.
    15.3 For each stack test, RATA, PM CEMS correlation, RRA, and 
RCA, you must also provide the information described in section 31 
of this appendix as a PDF file, either along with the quarterly 
compliance report (for stack tests) or together with the test 
results reported under appendix A, B, or C to this subpart or part 
75 of this chapter (for RATAs, RRAs, RCAs, or PM CEMS correlations).
    16.0 Applicable Reference Methods. One or more of the following 
EPA reference methods is needed for the tests described in sections 
14.1 through 14.3 of this appendix: Method 1, 2, 3A, 4, 5, 5D, 6C, 
26, 26A, 29, and/or 30B.
    16.1 Application of EPA test Methods 1 and 2. If you use 
periodic stack testing to comply with an output-based emissions 
limit, you must determine the stack gas flow rate during each 
performance test run in which EPA test Method 5, 5D, 26, 26A, 29, or 
30B is used, in order to convert the measured pollutant 
concentration to units of the standard. For EPA test Methods 5, 5D, 
26A and 29, which require isokinetic sampling, the delta-P readings 
made with the pitot tube and manometer at the EPA test Method 1 
traverse points, taken together with measurements of stack gas 
temperature, pressure, diluent gas concentration (from a separate 
EPA test Method 3A or 3B test) and moisture, provide the necessary 
data for the EPA test Method 2 flow rate calculations. Note that 
even if you elect to comply with a heat input-based standard, when 
EPA test Method 5, 5D, 26A, or 29 is used, you must still use EPA 
test Method 2 to determine the average stack gas velocity 
(vs), which is needed for the percent isokinetic 
calculation. The EPA test Methods 26 and 30B do not require 
isokinetic sampling; therefore, when either of these methods is 
used, if the stack gas flow rate is needed to comply with the 
applicable output-based emissions limit, you must make a separate 
EPA test Method 2 determination during each test run.
    16.2 Application of EPA test Method 3A. If you elect to perform 
periodic stack testing to comply with a heat input-based emissions 
limit, a separate measurement of the diluent gas (CO2 or 
O2) concentration is required for each test run in which 
EPA test Method 5, 5D, 26, 26A, 29, or 30B is used, in order to 
convert the measured pollutant concentration to units of the 
standard. The EPA test Method 3A is the preferred CO2 or 
O2 test method, although EPA test Method 3B may be used 
instead. Diluent gas measurements are also needed for stack gas 
molecular weight determinations when using EPA test Method 2.
    16.3 Application of EPA test Method 4. For performance stack 
tests, depending on which equation is used to convert pollutant 
concentration to units of the standard, measurement of the stack gas 
moisture content, using EPA test Method 4, may also be required for 
each test run. The EPA test Method 4 moisture data are also needed 
for the EPA test Method 2 calculations (to determine the molecular 
weight of the gas) and for the RATA of an Hg CEMS that measures on a 
wet basis, when EPA test Method 30B is used. Other applications that 
require EPA test Method 4 moisture determinations include: RATAs of 
an SO2 monitor, when the reference method and CEMS data 
are measured on a different moisture basis (wet or dry); conversion 
of wet-basis pollutant concentrations to the units of a heat input-
based emissions limit when certain EPA test Method 19 equations are 
used (e.g., Eq. 19-3, 19-4, or 19-8); and stack gas molecular weight 
determinations. When EPA test Method 5, 5D, 26A, or 29 is used for 
the performance test, the EPA test Method 4 moisture determination 
may be made by using the water collected in the impingers together 
with data from the dry gas meter; alternatively, a separate EPA test 
Method 4 determination may be made. However, when EPA test Method 26 
or 30B is used, EPA test Method 4 must be performed separately.
    16.4 Applications of EPA test Methods 5 and 5D. The EPA test 
Method 5 (or, if applicable 5D) must be used for the following 
applications: To demonstrate compliance with a filterable PM 
emissions limit; for PM tests used to set operating limits for PM 
CPMS; and for the initial correlations, RRAs and RCAs of a PM CEMS.
    16.5 Applications of EPA test Method 6C. If you elect to monitor 
SO2 emissions from your coal-fired EGU as a surrogate for 
HCl, the SO2 CEMS must be installed, certified, operated, 
and maintained according to 40 CFR part 75. Part 75 allows the use 
of EPA test Methods 6, 6A, 6B, and 6C for the required RATAs of the 
SO2 monitor. However, in practice, only instrumental EPA 
test Method 6C is used.
    16.6 Applications of EPA test Methods 26 and 26A. The EPA test 
Method 26A may be used for quarterly HCl or HF stack testing, or for 
the RATA of an HCl or HF CEMS. The EPA test Method 26 may be used 
for quarterly HCl or HF stack testing; however, for the RATAs of an 
HCl monitor that is following PS 18 and Procedure 6 in appendices B 
and F to part 60 of this chapter, EPA test Method 26 may only be 
used if approved upon request.
    16.7 Applications of EPA test Method 29. The EPA test Method 29 
may be used for periodic performance stack tests to determine 
compliance with individual or total HAP metals emissions limits. For 
coal-fired EGUs, the total HAP emissions limits exclude Hg.
    16.8 Applications of EPA test Method 30B. The EPA test Method 
30B is used for 30- (or 90-) boiler operating day Hg LEE tests and 
RATAs of Hg CEMS and sorbent trap monitoring systems, and it may be 
used for quarterly Hg stack testing (oil-fired EGUs, only).
    17.0 Facility and Test Company Information. In accordance with 
40 CFR 63.7(e)(3), a test is defined as three or more runs of one or 
more EPA Reference Method(s) conducted to measure the amount of a 
specific regulated pollutant, pollutants, or surrogates being 
emitted from a particular EGU (or group of EGUs that share a common 
stack), and to satisfy requirements of this subpart. On or after 
January 1, 2024, you must report the data elements in sections 17 
and 18, each time that you complete a required performance stack 
test, RATA, PM CEMS correlation, RRA, or RCA at the affected EGU(s), 
using EPA test Method 5, 5B, 5D, 6C, 26, 26A, 29, or 30B. You must 
also report the applicable data elements in sections 19 through 25 
of this appendix for each test. If any separate, corresponding EPA 
test Method 2, 3A, or 4 test is conducted in order to convert a 
pollutant concentration to the units of the applicable emission 
standard given in Table 1 or Table 2 of this subpart or to convert 
pollutant concentration from wet to dry basis (or vice-versa), you 
must also report the applicable data elements in sections 26 through 
31 of this appendix.
    The applicable data elements in sections 17 through 31 of this 
appendix must be submitted separately, in XML format, along with the 
quarterly Compliance Report (for stack tests) or along with the 
electronic test results submitted to the ECMPS Client Tool (for CMS 
performance evaluations). The Electronic Reporting Tool (ERT) or an 
equivalent schema can be utilized to create this XML file. Note: 
Ideally, for all of the tests completed at a given facility in a 
particular calendar quarter, the applicable data elements in 
sections 17 through 31 of this appendix should be submitted together 
in one XML file. However, as shown in Table 8 to this subpart, the 
timelines for submitting stack test results and CMS performance 
evaluations are not identical. Therefore, for calendar quarters in 
which both types of tests are completed, it may not be possible to 
submit the applicable data elements for all of those tests in a 
single XML file; separate submittals may be necessary to meet the 
applicable reporting deadlines.
    17.1 Part;
    17.2 Subpart;
    17.3 ORIS Code;
    17.4 Facility Name;
    17.5 Facility Address;
    17.6 Facility City;
    17.7 Facility County;
    17.8 Facility State;
    17.9 Facility Zip Code;
    17.10 Facility Point of Contact;
    17.11 Facility Contact Phone Number;
    17.12 Facility Contact Email;

[[Page 55778]]

    17.13 EPA Facility Registration System Number;
    17.14 Source Classification Code;
    17.15 State Facility ID;
    17.16 Project Number;
    17.17 Name of Test Company;
    17.18 Test Company Address;
    17.19 Test Company City;
    17.20 Test Company State;
    17.21 Test Company Zip Code;
    17.22 Test Company Point of Contact;
    17.23 Test Company Contact Phone Number;
    17.24 Test Company Contact Email; and
    17.25 Test Comment (optional, PM CPMS operating limits, if 
applicable).
    18.0 Source Information Data Elements. You must report the 
following data elements, as applicable, for each source for which at 
least one test is included in the XML file:
    18.1 Source ID (sampling location);
    18.2 Stack (duct) Diameter (circular stack) (in.);
    18.3 Equivalent Diameter (rectangular duct or stack) (in.);
    18.4 Area of Stack;
    18.5 Control Device Code; and
    18.6 Control Device Description.
    19.0 Run-Level and Lab Data Elements for EPA test Methods 5, 5B, 
5D, 26A, and 29. You must report the appropriate Source ID (i.e., 
Data Element 18.1) and the following data elements, as applicable, 
for each run of each performance stack test, PM CEMS correlation 
test, RATA, RRA, or RCA conducted using isokinetic EPA test Method 
5, 5B, 5D, or 26A. If your EGU is oil-fired and you use EPA test 
Method 26A to conduct stack tests for both HCl and HF, you must 
report these data elements separately for each pollutant. When you 
use EPA test Method 29 to measure the individual HAP metals, total 
filterable HAP metals and total HAP metals, report only the run-
level data elements (19.1, 19.3 through 19.30, and 19.38 through 
19.41), and the point-level and lab data elements in sections 20 and 
21 of this appendix:
    19.1 Test Number;
    19.2 Pollutant Name;
    19.3 EPA Test Method;
    19.4 Run Number;
    19.5 Corresponding Reference Method(s), if applicable;
    19.6 Corresponding Reference Method(s) Run Number, if 
applicable;
    19.7 Number of Traverse Points;
    19.8 Run Begin Date;
    19.9 Run Start Time (clock time start);
    19.10 Run End Date;
    19.11 Run End Time (clock time end);
    19.12 Barometric Pressure;
    19.13 Static Pressure;
    19.14 Cumulative Elapsed Sampling Time;
    19.15 Percent O2;
    19.16 Percent CO2;
    19.17 Pitot Tube ID;
    19.18 Pitot Tube Calibration Coefficient;
    19.19 Nozzle Calibration Diameter;
    19.20 F-Factor (Fd, Fw, or Fc);
    19.21 Calibration Coefficient of Dry Gas Meter (Y);
    19.22 Total Volume of Liquid Collected in Impingers and Silica 
Gel;
    19.23 Percent Moisture--Actual;
    19.24 Dry Molecular Weight of Stack Gas;
    19.25 Wet Molecular Weight of Stack Gas;
    19.26 Initial Reading of Dry Gas Meter Volume (dcf);
    19.27 Final Reading of Dry Gas Meter Volume (dcf);
    19.28 Stack Gas Velocity--fps;
    19.29 Stack Gas Flow Rate--dscfm;
    19.30 Type of Fuel;
    19.31 Pollutant Mass Collected (value);
    19.32 Pollutant Mass Unit of Measure;
    19.33 Detection Limit Flag;
    19.34 Pollutant Concentration;
    19.35 Pollutant Concentration Unit of Measure;
    19.36 Pollutant Emission Rate;
    19.37 Pollutant Emission Rate Units of Measure (in units of the 
standard);
    19.38 Compliance Limit Basis (heat input or electrical output);
    19.39 Heat Input or Electrical Output Unit of Measure;
    19.40 Process Parameter (value);
    19.41 Process Parameter Unit of Measure;
    19.42 Converted Concentration for PM CEMS only; and
    19.43 Converted Concentration Units (units of correlation for PM 
CEMS).
    20.0 Point-Level Data Elements for EPA test Methods 5, 5B, 5D, 
26A, & 29. To link the point-level data with the run data in the xml 
schema, you must report the Source ID (i.e., Data Element 18.1), EPA 
Test Method (Data Element 19.3), Run Number (Data Element 19.4), and 
Run Begin Date (Data Element 19.8) with the following point-level 
data elements for each run of each performance stack test, PM CEMS 
correlation test, RATA, RRA, or RCA conducted using isokinetic EPA 
test Method 5, 5B, 5D, 26A, or 29. Note that these data elements are 
required for all EPA test Method 29 applications, whether the method 
is being used to measure the total or individual HAP metals 
concentrations:
    20.1 Traverse Point ID;
    20.2 Stack Temperature;
    20.3 Differential Pressure Reading ([Delta]P);
    20.4 Orifice Pressure Reading ([Delta]H);
    20.5 Dry Gas Meter Inlet Temperature;
    20.6 Dry Gas Meter Outlet Temperature; and
    20.7 Filter Temperature.
    21.0 Laboratory Results for EPA test Methods 29 Total or 
Individual Multiple HAP Metals. If you use EPA test Method 29 and 
elect to comply with the total or individual HAP metals standards, 
you must report run-level data elements 19.1 through 19.34 in 
Section 19, and the point-level data elements in Section 20. To link 
the laboratory data with the run data in the xml schema, you must 
report the Source ID (i.e., Data Element 18.1), EPA Test Method 
(Data Element 19.3), Run Number (Data Element 19.4), and Run Begin 
Date (Data Element 19.8) with the results of the laboratory 
analyses. Regardless of whether you elect to comply with the total 
HAP metals standard or the individual HAP metals standard, you must 
report the front half catch, the back half catch, and the sum of the 
front and back half catches collected with EPA test Method 29 for 
each individual HAP metal and for the total HAP metals. The list of 
individual HAP metals is Antimony, Arsenic, Beryllium, Cadmium, 
Chromium, Cobalt, Lead, Manganese, Nickel, Selenium, and Mercury (if 
applicable). You must also calculate and report the pollutant 
emission rates(s) in relation to the standard(s) with which you have 
elected to comply and the units specified in Table 5 as follows:
    21.1 Each Individual HAP metal total mass collected:
    21.1.1 Pollutant Name;
    21.1.2 Pollutant Mass Collected;
    21.1.3 Pollutant Mass Units of Measure; and
    21.1.4 Detection Limit Flag.
    21.2 Each Individual HAP metal Front Half:
    21.2.1 Pollutant Name;
    21.2.2 Pollutant Mass Collected;
    21.2.3 Pollutant Mass Units of Measure; and
    21.2.4 Detection Limit Flag.
    21.3 Each Individual HAP metal Back Half:
    21.3.1 Pollutant Name;
    21.3.2 Pollutant Mass Collected;
    21.3.3 Pollutant Mass Units of Measure; and
    21.3.4 Detection Limit Flag.
    21.4 Each Individual HAP metal concentration:
    21.4.1 Pollutant Name;
    21.4.2 Pollutant Concentration; and
    21.4.3 Pollutant Concentration Units of Measure.
    21.5 Each Individual HAP metal emission rate in units of the 
standard:
    21.5.1 Pollutant Name;
    21.5.2 Pollutant Emission Rate; and
    21.5.3 Pollutant Emission Rate Units of Measure.
    21.6 Each Individual HAP metal emission rate in units of lbs/
MMBTU or lbs/MW (per Table 5):
    21.6.1 Pollutant Name;
    21.6.2 Pollutant Emission Rate; and
    21.6.3 Pollutant Emission Rate Units of Measure.
    21.7 Total Filterable HAP metals mass collected:
    21.7.1 Pollutant Name;
    21.7.2 Pollutant Mass Collected;
    21.7.3 Pollutant Mass Units of Measure; and
    21.7.4 Detection Limit Flag.
    21.8 Total Filterable HAP metals concentration:
    21.8.1 Pollutant Name;
    21.8.2 Pollutant Concentration; and
    21.8.3 Pollutant Concentration Units of Measure.
    21.9 Total Filterable HAP metals in units of lbs/MMBtu or lbs/MW 
(per Table 5):
    21.9.1 Pollutant Name;
    21.9.2 Pollutant Emission Rate; and
    21.9.3 Pollutant Emission Rate Units of Measure.
    21.10 Total HAP metals mass collected:
    21.10.1 Pollutant Name;
    21.10.2 Pollutant Mass Collected;
    21.10.3 Pollutant Mass Units of Measure; and
    21.10.4 Detection Limit Flag.
    21.11 Total HAP metals concentration
    21.11.1 Pollutant Name;
    21.11.2 Pollutant Concentration; and
    21.11.3 Pollutant Concentration Units of Measure.
    21.12 Total HAP metals Emission Rate in Units of the Standard:

[[Page 55779]]

    21.12.1 Pollutant Name;
    21.12.2 Pollutant Emission Rate; and
    21.12.3 Pollutant Emission Rate Units of Measure.
    21.13 Total HAP metals Emission Rate in lbs/MMBtu or lbs/MW (per 
Table 5):
    21.13.1 Pollutant Name;
    21.13.2 Pollutant Emission Rate; and
    21.13.3 Pollutant Emission Rate Units of Measure.
    22.0 Run-Level and Lab Data Elements for EPA test Method 26. If 
you use EPA test Method 26, you must report the Source ID (i.e., 
Data Element 18.1) and the following run-level data elements for 
each test run. If your EGU is oil-fired and you use EPA test Method 
26 to conduct stack tests for both HCl and HF, you must report these 
data elements separately for each pollutant:
    22.1 Test Number;
    22.2 Pollutant Name;
    22.3 EPA Test Method;
    22.4 Run Number;
    22.5 Corresponding Reference Method(s), if applicable;
    22.6 Corresponding Reference Method(s) Run Number, if 
applicable;
    22.7 Number of Traverse Points;
    22.8 Run Begin Date;
    22.9 Run Start Time (clock start time);
    22.10 Run End Date;
    22.11 Run End Time (clock end time);
    22.12 Barometric Pressure;
    22.13 Cumulative Elapsed Sampling Time;
    22.14 Calibration Coefficient of Dry Gas Meter (Y);
    22.15 Initial Reading of Dry Gas Meter Volume (dcf);
    22.16 Final Reading of Dry Gas Meter Volume (dcf);
    22.17 Percent O2;
    22.18 Percent CO2;
    22.19 Type of Fuel;
    22.20 F-Factor (Fd, Fw, or Fc);
    22.21 Pollutant Mass Collected (value);
    22.22 Pollutant Mass Units of Measure;
    22.23 Detection Limit Flag;
    22.24 Pollutant Concentration;
    22.25 Pollutant Concentration Unit of Measure;
    22.26 Compliance Limit Basis (heat input or electrical output);
    22.27 Heat Input or Electrical Output Unit of Measure;
    22.28 Process Parameter (value);
    22.29 Process Parameter Unit of Measure;
    22.30 Pollutant Emission Rate; and
    22.31 Pollutant Emission Rate Units of Measure (in the units of 
the standard).
    23.0 Point-Level Data Elements for EPA test Method 26. To link 
the point-level data in this section with the run-level data in the 
XML schema, you must report the Source ID (i.e., Data Element 18.1), 
EPA Test Method (Data Element 22.3), Run Number (Data Element 22.4), 
and Run Begin Date (Data Element 22.8) from section 22 and the 
following point-level data elements for each run of each EPA test 
Method 26 test:
    23.1 Traverse Point ID;
    23.2 Filter Temperature; and
    23.3 Dry Gas Meter Temperature.
    24.0 Run-Level Data for EPA test Method 30B. You must report 
Source ID (i.e. Data Element 18.1) and the following run-level data 
elements for each EPA test Method 30B test run:
    24.1 Test Number;
    24.2 Pollutant Name;
    24.3 EPA Test Method;
    24.4 Run Number;
    24.5 Corresponding Reference Method(s), if applicable;
    24.6 Corresponding Reference Method(s) Run Number, if 
applicable;
    24.7 Number of Traverse Points;
    24.8 Run Begin Date;
    24.9 Run Start Time (clock time start);
    24.10 Run End Date;
    24.11 Run End Time (clock time end);
    24.12 Barometric Pressure;
    24.13 Percent O2;
    24.14 Percent CO2;
    24.15 Cumulative Elapsed Sampling Time;
    24.16 Calibration Coefficient of Dry Gas Meter Box A (Y);
    24.17 Initial Reading of Dry Gas Meter Volume (A);
    24.18 Final Reading of Dry Gas Meter Volume (A);
    24.19 Calibration Coefficient of Dry Gas Meter Box B (Y);
    24.20 Initial Reading of Dry Gas Meter Volume (B);
    24.21 Final Reading of Dry Gas Meter Volume (B);
    24.22 Gas Sample Volume Units of Measure;
    24.23 Post-Run Leak Rate (A);
    24.24 Post-Run Leak Check Vacuum (A);
    24.25 Post-Run Leak Rate (B);
    24.26 Post-Run Leak Check Vacuum (B);
    24.27 Sorbent Trap ID (A);
    24.28 Pollutant Mass Collected, Section 1 (A);
    24.29 Pollutant Mass Collected, Section 2 (A);
    24.30 Mass of Spike on Sorbent Trap A;
    24.31 Total Pollutant Mass Trap A;
    24.32 Sorbent Trap ID (B);
    24.33 Pollutant Mass Collected, Section 1 (B);
    24.34 Pollutant Mass Collected, Section 2 (B);
    24.35 Mass of Spike on Sorbent Trap B;
    24.36 Total Pollutant Mass Trap B;
    24.37 Pollutant Mass Units of Measure;
    24.38 Pollutant Average Concentration;
    24.39 Pollutant Concentration Units of Measure;
    24.40 Method Detection Limit;
    24.41 Percent Spike Recovery;
    24.42 Type of Fuel;
    24.43 F-Factor (Fd, Fw, or Fc);
    24.44 Compliance Limit Basis (heat input or electrical output);
    24.45 Heat Input or Electrical Output Unit of Measure;
    24.46 Process Parameter (value);
    24.47 Process Parameter Unit of Measure;
    24.48 Pollutant Emission Rate; and
    24.49 Pollutant Emission Rate Unit of Measure (in the units of 
the standard).
    25.0 Point-Level Data Elements for EPA test Method 30B. You must 
report the Source ID (i.e., Data Element 18.1), EPA Test Method 
(Data Element 24.3), Run Number (Data Element 24.4), and Run Begin 
Date (Data Element 24.8) and the following point-level data elements 
for each run of each EPA test Method 30B test:
    25.1 Traverse Point ID;
    25.2 Dry Gas Meter Temperature (A);
    25.3 Sample Flow Rate (A) (L/min);
    25.4 Dry Gas Meter Temperature (B); and
    25.5 Sample Flow Rate (B) (L/min).
    26.0 Pre-Run Data Elements for EPA test Methods 3A and 6C. You 
must report the Source ID (i.e., Data Element 18.1) and the 
following pre-run data elements for each SO2 RATA using 
instrumental EPA test Method 6C, and for each instrumental EPA test 
Method 3A O2 or CO2 test that is performed to 
convert a pollutant concentration to the units of measure of the 
applicable emission unit of standard in Table 1 or 2 of this 
subpart:
    26.1 Test Number;
    26.2 EPA Test Method;
    26.3 Calibration Gas Cylinder Analyte;
    26.4 Cylinder Gas Units of Measure;
    26.5 Date of Calibration;
    26.6 Calibration Low-Level Gas Cylinder ID;
    26.7 Calibration Low-Level Gas Concentration;
    26.8 Calibration Low-Level Cylinder Expiration Date;
    26.9 Calibration Mid-Level Gas Cylinder ID;
    26.10 Calibration Mid-Level Gas Concentration;
    26.11 Calibration Mid-Level Cylinder Expiration Date;
    26.12 Calibration High-Level Gas Cylinder ID;
    26.13 Calibration Span (High-Level) Gas Concentration;
    26.14 Calibration High-Level Cylinder Expiration Date;
    26.15 Low-Level Gas Response;
    26.16 Low-Level Calibration Error;
    26.17 Low-Level Alternate Performance Specification (APS) Flag;
    26.18 Mid-Level Gas Response;
    26.19 Mid-Level Calibration Error;
    26.20 Mid-Level APS Flag;
    26.21 High-Level Gas Response;
    26.22 High-Level Calibration Error; and
    26.23 High-Level APS Flag.
    27.0 Run-Level Data Elements for EPA test Methods 3A and 6C. You 
must report the Source ID (i.e., Data Element 18.1) and following 
run-level data elements for each run of each SO2 RATA 
using instrumental EPA test Method 6C, and for each run of each 
corresponding instrumental EPA test Method 3A test that is performed 
to convert a pollutant concentration to the applicable emission unit 
of standard in Table 1 or 2 of this subpart:
    27.1 Test Number;
    27.2 Pollutant or Analyte Name;
    27.3 EPA Test Method;
    27.4 Run Number;
    27.5 Corresponding Reference Method(s), if applicable;
    27.6 Corresponding Reference Method(s) Run Number(s), if 
applicable;
    27.7 Number of Traverse Points;
    27.8 Run Begin Date;
    27.9 Run Start Time (clock time start);
    27.10 Run End Date;
    27.11 Run End Time (clock time end);
    27.12 Cumulative Elapsed Sampling Time;
    27.13 Upscale (mid or high) Gas Level;

[[Page 55780]]

    27.14 Pre-Run Low-Level Response;
    27.15 Pre-Run Low-Level System Bias;
    27.16 Pre-Run Low-Level Bias APS Flag;
    27.17 Pre-Run Upscale (mid or high) Response;
    27.18 Pre-Run Upscale (mid or high) System Bias;
    27.19 Pre-Run Upscale (mid or high) Bias APS Flag;
    27.20 Post-Run Low-Level Response;
    27.21 Post-Run Low-Level System Bias;
    27.22 Post-Run Low-Level Bias APS Flag;
    27.23 Post-Run Low-Level Drift;
    27.24 Post-Run Low-Level Drift APS Flag;
    27.25 Post-Run Upscale (mid or high) Response;
    27.26 Post-Run Upscale (mid or high) System Bias;
    27.27 Post-Run Upscale (mid or high) System Bias APS Flag;
    27.28 Post-Run Upscale (mid or high) Drift;
    27.29 Post-Run Upscale (mid or high) Drift APS Flag;
    27.30 Unadjusted Raw Emissions Average Concentration;
    27.31 Calculated Average Concentration, Adjusted for Bias 
(Cgas);
    27.32 Concentration Units of Measure (Dry or wet);
    27.33 Type of Fuel;
    27.34 Process Parameter (value); and
    27.35 Process Parameter Units of Measure.
    28.0 Run-Level Data Elements for EPA test Method 2. When you 
make a separate determination of the stack gas flow rate using EPA 
test Method 2 separately, corresponding to a pollutant reference 
method test, i.e., when data from the pollutant reference method 
cannot determine the stack gas flow rate, you must report the Source 
ID (i.e., Data Element 18.1) and following run-level data elements 
for each EPA test Method 2 test run:
    28.1 Test Number;
    28.2 EPA Test Method;
    28.3 Run Number;
    28.4 Number of Traverse Points;
    28.5 Run Begin Date;
    28.6 Run Start Time (clock time start);
    28.7 Run End Date;
    28.8 Run End Time (clock time end);
    28.9 Pitot Tube ID;
    28.10 Pitot Tube Calibration Coefficient;
    28.11 Barometric Pressure;
    28.12 Static Pressure;
    28.13 Percent O2;
    28.14 Percent CO2;
    28.15 Percent Moisture--actual;
    28.16 Dry Molecular Weight of Stack Gas;
    28.17 Wet Molecular Weight of Stack Gas;
    28.18 Stack Gas Velocity--fps; and
    28.19 Stack Gas Flow Rate--dscfm.
    29.0 Point-Level Data Elements for EPA test Method 2. For each 
run of each separate EPA test Method 2 test, you must report the 
Source ID (i.e., Data Element 18.1), EPA Test Method (Data Element 
28.2), Run Number (Data Element 28.3), and Run Begin Date (Data 
Element 28.5) and the following point-level data elements:
    29.1 Traverse Point ID;
    29.2 Stack Temperature; and
    29.3 Differential Pressure Reading ([Delta]P).
    30.0 Run-Level Data Elements for EPA test Method 4. When you 
make a separate EPA test Method 4 determination of the stack gas 
moisture content corresponding to a pollutant reference method test, 
i.e., when data from the pollutant reference method cannot determine 
the moisture content, you must report the Source ID (i.e., Data 
Element 18.1) and the following run-level data elements for each EPA 
test Method 4 test run:
    30.1 Test Number;
    30.2 EPA Test Method;
    30.3 Run Number;
    30.4 Number of Traverse Points;
    30.5 Run Begin Date;
    30.6 Run Start Time (clock time start);
    30.7 Run End Date;
    30.8 Run End Time (clock time end);
    30.9 Barometric Pressure;
    30.10 Calibration Coefficient of Dry Gas Meter (Y);
    30.11 Volume of Water Collected in Impingers and Silica Gel;
    30.12 Percent Moisture-actual;
    30.13 Initial Reading of Dry Gas Meter Volume (dcf);
    30.14 Final Reading of Dry Gas Meter Volume (dcf); and
    30.15 Dry Gas Meter Temperature (average).
    31.0 Other Information for Each Test or Test Series. You must 
provide each test included in the XML data file described in this 
appendix with supporting documentation, in a PDF file submitted 
concurrently with the XML file, such that all the data required to 
be reported by 40 CFR 63.7(g) are provided. That supporting data 
include but are not limited to diagrams showing the location of the 
test site and the sampling points, laboratory report(s) including 
analytical calibrations, calibrations of source sampling equipment, 
calibration gas cylinder certificates, raw instrumental data, field 
data sheets, quality assurance data (e.g. field recovery spikes) and 
any required audit results and stack testers' credentials (if 
applicable). The applicable data elements in 40 CFR 
63.10031(f)(6)(i) through (xii) of this section must be entered into 
ECMPS with each PDF submittal; the test number(s) (see 40 CFR 
63.10031(f)(6)(xi)) must be included. The test number(s) must match 
the test number(s) in sections 19 through 31 of this appendix (as 
applicable).

[FR Doc. 2020-15950 Filed 9-8-20; 8:45 am]
BILLING CODE 6560-50-P