[Federal Register Volume 89, Number 18 (Friday, January 26, 2024)]
[Proposed Rules]
[Pages 5318-5381]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2024-00938]



[[Page 5317]]

Vol. 89

Friday,

No. 18

January 26, 2024

Part II





Environmental Protection Agency





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40 CFR Parts 2 and 99





Waste Emissions Charge for Petroleum and Natural Gas Systems; Proposed 
Rule

  Federal Register / Vol. 89 , No. 18 / Friday, January 26, 2024 / 
Proposed Rules  

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ENVIRONMENTAL PROTECTION AGENCY

40 CFR Parts 2 and 99

[EPA-HQ-OAR-2023-0434; FRL-10246.1-01-OAR]
RIN 2060-AW02


Waste Emissions Charge for Petroleum and Natural Gas Systems

ACTION: Proposed rule.

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SUMMARY: The Environmental Protection Agency (EPA) is proposing a 
regulation to implement the requirements of the Clean Air Act (CAA) as 
specified in the Methane Emissions Reduction Program of the Inflation 
Reduction Act. This program requires the EPA to impose and collect an 
annual charge on methane emissions that exceed specified waste 
emissions thresholds from an owner or operator of an applicable 
facility that reports more than 25,000 metric tons of carbon dioxide 
equivalent of greenhouse gases emitted per year pursuant to the 
petroleum and natural gas systems source category requirements of the 
Greenhouse Gas Reporting Rule. The proposal would implement calculation 
procedures, flexibilities, and exemptions related to the waste 
emissions charge and proposes to establish confidentiality 
determinations for data elements included in waste emissions charge 
filings.

DATES: 
    Comments. Comments must be received on or before March 11, 2024. 
Under the Paperwork Reduction Act (PRA), comments on the information 
collection provisions are best assured of consideration if the Office 
of Management and Budget (OMB) receives a copy of your comments on or 
before February 26, 2024.
    Public hearing. The EPA will conduct a virtual public hearing on 
February 12, 2024. See SUPPLEMENTARY INFORMATION for information on 
registering for a public hearing.

ADDRESSES: 
    Comments. You may submit comments, identified by Docket ID No. EPA-
HQ-OAR-2023-0434, by any of the following methods:
    Federal eRulemaking Portal. https://www.regulations.gov (our 
preferred method). Follow the online instructions for submitting 
comments.
    Mail: U.S. Environmental Protection Agency, EPA Docket Center, Air 
and Radiation Docket, Mail Code 28221T, 1200 Pennsylvania Avenue NW, 
Washington, DC 20460.
    Hand Delivery or Courier (by scheduled appointment only): EPA 
Docket Center, WJC West Building, Room 3334, 1301 Constitution Avenue 
NW, Washington, DC 20004. The Docket Center's hours of operations are 
8:30 a.m.-4:30 p.m., Monday-Friday (except Federal holidays).
    Instructions: All submissions received must include the Docket ID 
No. for this proposed rulemaking. Comments received may be posted 
without change to https://www.regulations.gov, including any personal 
information provided. For detailed instructions on sending comments and 
additional information on the rulemaking process, see the ``Public 
Participation'' heading of the SUPPLEMENTARY INFORMATION section of 
this document.
    The virtual hearing will be held using an online meeting platform, 
and the EPA has provided information on its website (https://www.epa.gov/inflation-reduction-act/methane-emissions-reduction-program-merp) regarding how to register and access the hearing. Refer 
to the SUPPLEMENTARY INFORMATION section for additional information.

FOR FURTHER INFORMATION CONTACT: For questions about this proposed 
action, contact Mr. Shaun Ragnauth, Climate Change Division, Office of 
Atmospheric Programs (MC-6207A), Environmental Protection Agency, 1200 
Pennsylvania Ave. NW, Washington, DC 20460; telephone number: (202) 
343-9142; email address: [email protected].
    World wide web (WWW). In addition to being available in the docket, 
an electronic copy of this proposal will also be available through the 
WWW. Following the Administrator's signature, a copy of this proposed 
rule will be posted on the EPA's Inflation Reduction Act Methane 
Emissions Reduction Program website at https://www.epa.gov/inflation-reduction-act/methane-emissions-reduction-program.

SUPPLEMENTARY INFORMATION: 
    Written comments. Submit your comments, identified by Docket ID No. 
EPA-HQ-OAR-2023-0434, at https://www.regulations.gov (our preferred 
method), or the other methods identified in the ADDRESSES section. Once 
submitted, comments cannot be edited or removed from the docket. The 
EPA may publish any comment received to its public docket. Do not 
submit to the EPA's docket at https://www.regulations.gov any 
information you consider to be confidential business information (CBI), 
proprietary business information (PBI), or other information whose 
disclosure is restricted by statute. Multimedia submissions (audio, 
video, etc.) must be accompanied by a written comment. The written 
comment is considered the official comment and should include 
discussion of all points you wish to make. The EPA will generally not 
consider comments or comment contents located outside of the primary 
submission (i.e., on the web, cloud, or other file sharing system). 
Commenters who would like the EPA to further consider in this 
rulemaking comments relevant to this rulemaking that they previously 
provided on any other rulemaking or request for information (e.g., the 
Greenhouse Gas Reporting Rule: Revisions and Confidentiality 
Determinations for Petroleum and Natural Gas Systems, Docket ID No. 
EPA-HQ-OAR-2023-0234, the Methane Emissions Reduction Program Request 
for Information, Docket ID No. EPA-HQ-OAR-2022-0875, and the Standards 
of Performance for New, Reconstructed, and Modified Sources and 
Emissions Guidelines for Existing Sources: Oil and Natural Gas Sector 
Climate Review, Docket ID No. EPA-HQ-OAR-2021-0317) must submit those 
comments to the EPA during this proposal's comment period. Please visit 
https://www.epa.gov/dockets/commenting-epa-dockets for additional 
submission methods; the full EPA public comment policy; information 
about CBI, PBI, or multimedia submissions, and general guidance on 
making effective comments.
    Participation in virtual public hearing. The EPA will begin pre-
registering speakers for the hearing no later than one business day 
after publication in the Federal Register. To register to speak at the 
virtual hearing, please use the online registration form available at 
https://www.epa.gov/inflation-reduction-act/methane-emissions-reduction-program or contact us by email at [email protected]. The last day 
to pre-register to speak at the hearing will be February 7, 2024. On 
February 9, 2024, the EPA will post a general agenda that will list 
pre-registered speakers in approximate order at https://www.epa.gov/inflation-reduction-act/methane-emissions-reduction-program.
    The EPA will make reasonable efforts to follow the schedule as 
closely as practicable on the day of the hearing; however, please plan 
for the hearings to run either ahead of schedule or behind schedule.
    Each commenter will have 4 minutes to provide oral testimony. The 
EPA encourages commenters to provide the EPA with a copy of their oral 
testimony electronically (via email) by emailing it to [email protected]. 
The EPA also recommends submitting the text of your oral testimony as 
written comments to the rulemaking docket.

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    The EPA may ask clarifying questions during the oral presentations 
but will not respond to the presentations at that time. Written 
statements and supporting information submitted during the comment 
period will be considered with the same weight as oral testimony and 
supporting information presented at the public hearing.
    Please note that any updates made to any aspect of the hearing will 
be posted online at https://www.epa.gov/inflation-reduction-act/methane-emissions-reduction-program. While the EPA expects the hearing 
to go forward as set forth above, please monitor our website or contact 
us by email at [email protected] to determine if there are any updates. The 
EPA does not intend to publish a document in the Federal Register 
announcing updates.
    If you require the services of an interpreter or special 
accommodation such as audio description, please pre-register for the 
hearing with the public hearing team and describe your needs by 
February 2, 2024. The EPA may not be able to arrange accommodations 
without advanced notice.
    Regulated entities. This is a proposed regulation. If finalized, 
the regulation would affect certain owners or operators of facilities 
in certain segments of the petroleum and natural gas systems industry 
that report more than 25,000 metric tons (mt) of carbon dioxide 
equivalent (CO2e) pursuant to the requirements codified at 
40 CFR part 98, subpart W (Petroleum and Natural Gas Systems) 
(hereafter referred to as ``part 98, subpart W''). Per the requirements 
of CAA section 136(d), the industry segments to which the waste 
emissions charge may apply are offshore petroleum and natural gas 
production, onshore petroleum and natural gas production, onshore 
natural gas processing, onshore gas transmission compression, 
underground natural gas storage, liquefied natural gas storage, 
liquefied natural gas import and export equipment, onshore petroleum 
and natural gas gathering and boosting, and onshore natural gas 
transmission pipeline. Regulated categories and entities include, but 
are not limited to, those listed in Table 1 of this preamble:

                               Table 1--Examples of Affected Entities by Category
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                                                 North American Industry
                    Category                      Classification System       Examples of affected facilities
                                                         (NAICS)
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Petroleum and Natural Gas Systems..............                   486210  Pipeline transportation of natural
                                                                  221210   gas.
                                                                  211120  Natural gas distribution facilities.
                                                                  211130  Crude petroleum extraction.
                                                                          Natural gas extraction.
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    Table 1 of this preamble is not intended to be exhaustive, but 
rather provides a guide for readers regarding facilities likely to be 
affected by this proposed action. This table lists the types of 
facilities that the EPA is now aware could potentially be affected by 
this action. Other types of facilities than those listed in the table 
could also be subject to reporting requirements. To determine whether 
you would be affected by this proposed action, you should carefully 
examine the applicability criteria found in 40 CFR part 99, subpart A 
(General Provisions). If you have questions regarding the applicability 
of this action to a particular facility, consult the person listed in 
the FOR FURTHER INFORMATION CONTACT section.
    Acronyms and abbreviations. The following acronyms and 
abbreviations are used in this document.
AMLD Advanced Mobile Leak Detection
API American Petroleum Institute
ASTM American Society for Testing and Materials
BOEM Bureau of Ocean Energy Management
CAA Clean Air Act
CBI confidential business information
CEMS continuous emission monitoring system
CFR Code of Federal Regulations
CH4 methane
CO2 carbon dioxide
CO2e carbon dioxide equivalent
e-GGRT electronic Greenhouse Gas Reporting Tool
EF emission factor
EG emission guidelines
EIA Energy Information Administration
EPA U.S. Environmental Protection Agency
ET Eastern time
FAQ frequently asked question
FR Federal Register
GHG greenhouse gas
GHGRP Greenhouse Gas Reporting Program
GOR gas-to-oil ratio
GRI Gas Research Institute
GWP Global Warming Potential
IRA Inflation Reduction Act of 2022
ICR Information Collection Request
ISBN International Standard Book Number
ISO International Standards Organization
LDC local distribution company
LNG liquified natural gas
mmBtu million British thermal units
MMscf million standard cubic feet
mt metric tons
N2O nitrous oxide
NAICS North American Industry Classification System
NGLs natural gas liquids
NIST National Institute of Standards and Technology
NSPS new source performance standards
OEM original equipment manufacturer
OGI optical gas imaging
OMB Office of Management and Budget
PBI proprietary business information
ppm parts per million
PRA Paperwork Reduction Act
RFA Regulatory Flexibility Act
RY reporting year
scfh standard cubic feet per hour
TSD technical support document
U.S. United States
UMRA Unfunded Mandates Reform Act of 1995
UNFCCC United Nations Framework Convention on Climate Change
VOC volatile organic compound
WEC waste emissions charge
WWW World Wide Web

Table of Contents

I. Background

A. How is this Preamble Organized?
B. Executive Summary
C. Background and Related Actions
D. Legal Authority

II. Requirements To Implement the Waste Emissions Charge

A. Proposed Definitions To Support WEC Implementation
B. Waste Emissions Thresholds
C. Common Ownership or Control for Netting of Emissions
D. Exemptions to the Waste Emissions Charge

III. General Requirements of the Proposed Rule

A. WEC Reporting Requirements
B. Remittance and Assessment of WEC
C. Authorizing the Designated Representative
D. General Recordkeeping Requirements
E. General Provisions, Including Auditing and Compliance and 
Enforcement

IV. Proposed Confidentiality Determinations for Certain Data Reporting 
Elements

A. Overview and Background
B. Proposed Confidentiality Determinations
C. Proposed Amendments to 40 CFR Part 2
D. Proposed Changes to Confidentiality Determinations for Data 
Elements Reported Under Subpart W

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E. Request for Comments on Proposed Category Assignments, 
Confidentiality Determinations, or Reporting Determinations

V. Impacts of the Proposed Rule

VI. Statutory and Executive Order Reviews

A. Executive Order 12866: Regulatory Planning and Review and 
Executive Order 14094: Modernizing Regulatory Review
B. Paperwork Reduction Act (PRA)
C. Regulatory Flexibility Act (RFA)
D. Unfunded Mandates Reform Act (UMRA)
E. Executive Order 13132: Federalism
F. Executive Order 13175: Consultation and Coordination With Indian 
Tribal Governments
G. Executive Order 13045: Protection of Children From Environmental 
Health Risks and Safety Risks
H. Executive Order 13211: Actions That Significantly Affect Energy 
Supply, Distribution, or Use
I. National Technology Transfer and Advancement Act
J. Executive Order 12898: Federal Actions To Address Environmental 
Justice in Minority Populations and Low-Income Populations and 
Executive Order 14096: Revitalizing our Nation's Commitment to 
Environmental Justice for All
K. Determination under CAA Section 307(d)

I. Background

A. How is this preamble organized?

    The first section (section I.) of this preamble contains background 
information regarding the proposed rule. This section also discusses 
the EPA's legal authority under the Clean Air Act (CAA) to promulgate 
implementing regulations for the waste emissions charge, proposed to be 
codified at 40 CFR part 99 (hereafter referred to as ``part 99''). 
Section I. of the preamble also discusses the EPA's legal authority to 
make confidentiality determinations for new data elements included in 
waste emissions charge filings (WEC filings) required by the proposed 
rule. Section II. of this preamble contains detailed information on the 
proposed provisions necessary to implement CAA section 136(c) through 
(g), including exemptions. Section III. of this preamble describes the 
general requirements for the proposed rule. Section IV. of this 
preamble discusses the proposed confidentiality determinations for new 
data reporting elements for the proposed part 99 and also discusses 
confidentiality determinations for two data elements reported under 
part 98, subpart W. Section V. of this preamble discusses the impacts 
of the proposed part 99. Section VI. of this preamble describes the 
statutory and Executive order requirements applicable to this proposed 
action.

B. Executive Summary

    In August 2022, Congress passed, and President Biden signed, the 
Inflation Reduction Act of 2022 (IRA) into law. Section 60113 of the 
IRA amended the CAA by adding section 136, ``Methane Emissions and 
Waste Reduction Incentive Program for Petroleum and Natural Gas 
Systems.'' CAA section 136(c) directs the Administrator of the EPA to 
impose and collect a ``Waste Emissions Charge'' on methane emissions 
that exceed statutorily specified waste emissions thresholds from 
owners or operators of applicable facilities. The waste emissions 
threshold is a facility-specific amount of metric tons of methane 
emissions calculated using the segment-specific methane intensity 
thresholds defined in CAA section 136(f)(1) through (3) and a 
facility's natural gas throughput (or oil throughput in certain 
circumstances). Facilities that have methane emissions below the 
threshold would not be required to pay the charge; facilities that have 
emissions above the threshold would be required to pay the charge. The 
waste emissions charge, or WEC, is specified in CAA section 136 to 
begin for emissions occurring in 2024 at $900 per metric ton of methane 
exceeding the threshold, increasing to $1,200 per metric ton of methane 
in 2025, and to $1,500 per metric ton of methane in 2026 and years 
after. The WEC only applies to the subset of a facility's emissions 
that are above the waste emissions threshold.
    The WEC program applies to facilities that report more than 25,000 
mt CO2e of greenhouse gases emitted per year pursuant to the 
Greenhouse Gas Reporting Rule's requirements for the petroleum and 
natural gas systems source category (codified as 40 CFR part 98, 
subpart W).\1\ An applicable facility, as defined in CAA section 
136(d), is a facility within the following industry segments (as the 
following industry segments are defined in part 98, subpart W): onshore 
petroleum and natural gas production, offshore petroleum and natural 
gas production, onshore petroleum and natural gas gathering and 
boosting, onshore natural gas processing, onshore gas transmission 
compression, onshore natural gas transmission pipeline, underground 
natural gas storage, liquefied natural gas import and export equipment, 
and liquefied natural gas storage.\2\ Congress structured the WEC so 
that it focuses on high-emitting oil and gas facilities (i.e., those 
with emissions greater than 25,000 mt CO2e of greenhouse 
gases emitted per year and that have a methane emissions intensity in 
excess of the statutory threshold).
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    \1\ 42 U.S.C. 7436(c) (``The Administrator shall impose and 
collect a charge on methane emissions that exceed an applicable 
waste emissions threshold under subsection (f) from an owner or 
operator of an applicable facility that reports more than 25,000 
metric tons of carbon dioxide equivalent of greenhouse gases emitted 
per year pursuant to subpart W of part 98 of title 40, Code of 
Federal Regulations, regardless of the reporting threshold under 
that subpart.'').
    \2\ 42 U.S.C. 7436(d).
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    CAA section 136 defines three important elements of the WEC 
program: (1) waste emissions thresholds; (2) netting of emissions 
across different facilities; and (3) exemptions for certain emissions 
and facilities. Facilities may owe a WEC obligation if their subpart W 
reported emissions exceed facility-specific waste emissions thresholds 
specified in CAA section 136(f).\3\ Facility efficiency in terms of 
methane emissions per unit of production or throughput would have a 
large impact on the amount of the WEC owed, with more efficient 
facilities expected to have emissions falling below the specified 
thresholds.
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    \3\ 42 U.S.C. 7436(f)(1-3).
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    Some facilities may have emissions that are below the waste 
emissions thresholds, and some facilities may have emissions above the 
thresholds. CAA section 136(f)(4) allows facilities under common 
ownership or control to net emissions across those facilities, which 
could result in a reduced total charge, or avoidance of the charge.\4\
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    \4\ 42 U.S.C. 7436(f)(4) (``In calculating the total emissions 
charge obligation for facilities under common ownership or control, 
the Administrator shall allow for the netting of emissions by 
reducing the total obligation to account for facility emissions 
levels that are below the applicable thresholds within and across 
all applicable segments identified in subsection (d).'').
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    In addition, there are three exemptions that may lower a facility's 
WEC or exempt the facility entirely from the charge. The first 
exemption, found in CAA section 136(f)(5), exempts from the charge 
emissions occurring at facilities in the onshore or offshore petroleum 
and natural gas production industry segments that are caused by 
eligible delays in environmental permitting of gathering or 
transmission infrastructure.\5\ The second exemption, found in CAA 
section 136(f)(6), exempts from the charge, if certain conditions are 
met, those facilities that are subject to and in compliance with final 
methane

[[Page 5321]]

emissions requirements promulgated pursuant to CAA sections 111(b) and 
(d).\6\ This exemption becomes available only if a determination is 
made by the Administrator that such final requirements are approved and 
in effect in all states with respect to the applicable facilities, and 
that the emissions reductions resulting from those final requirements 
will achieve equivalent or greater emission reductions as would have 
resulted from the EPA's proposed methane emissions requirements from 
2021.\7\ The third exemption, found in CAA section 136(f)(7), exempts 
from the charge reporting-year emissions from wells that are 
permanently shut in and plugged.\8\ In this action, the EPA proposes 
specific requirements for eligibility for each of these exemptions.
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    \5\ 42 U.S.C. 7436(f)(5). (``Charges shall not be imposed 
pursuant to paragraph (1) on emissions that exceed the waste 
emissions threshold specified in such paragraph if such emissions 
are caused by unreasonable delay, as determined by the 
Administrator, in environmental permitting of gathering or 
transmission infrastructure necessary for offtake of increased 
volume as a result of methane emissions mitigation 
implementation.'')
    \6\ 42 U.S.C. 7436(f)(6) (``Charges shall not be imposed 
pursuant to subsection (c) on an applicable facility that is subject 
to and in compliance with methane emissions requirements pursuant to 
subsections (b) and (d) of section 7411 of this title upon a 
determination by the Administrator that--(i) methane emissions 
standards and plans pursuant to subsections (b) and (d) of section 
7411 of this title have been approved and are in effect in all 
States with respect to the applicable facilities; and (ii) 
compliance with the requirements described in clause (i) will result 
in equivalent or greater emissions reductions as would be achieved 
by the proposed rule of the Administrator entitled ``Standards of 
Performance for New, Reconstructed, and Modified Sources and 
Emissions Guidelines for Existing Sources: Oil and Natural Gas 
Sector Climate Review'' (86 FR 63110 (November 15, 2021)), if such 
rule had been finalized and implemented.'').
    \7\ Id.
    \8\ 42 U.S.C. 7436(f)(7). ('' Charges shall not be imposed with 
respect to the emissions rate from any well that has been 
permanently shut-in and plugged in the previous year in accordance 
with all applicable closure requirements, as determined by the 
Administrator.'')
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    The EPA proposes to require that the WEC would be quantified and 
paid through a WEC filing submitted no later than March 31 of each 
calendar year for methane emissions that occurred in the previous 
calendar year (subpart W reporting year). The WEC filing would include 
information relevant to calculating the WEC, such as identification of 
facilities included in netting, eligibility for exemptions from WEC, 
and supporting information necessary for the EPA to verify information 
submitted regarding exemptions.
    The proposed provisions of part 99 under this rulemaking are 
described in further detail in sections II. and III. of this preamble.

C. Background and Related Actions

    Congress designed the WEC to work in tandem with several related 
EPA programs. The WEC provides an incentive for the early adoption of 
methane emission reduction practices and technologies such as those 
that required under the Standards of Performance for New, 
Reconstructed, and Modified Sources and Emissions Guidelines for 
Existing Sources: Oil and Natural Gas Sector Climate Review (NSPS 
OOOOb/EG OOOOc), which Congress expected to be promulgated pursuant to 
CAA section 111. The sooner facilities adopt the methodologies and 
technologies required in those rules, the lower their assessed WEC; at 
full implementation of those rules, the EPA expects many of the WEC-
affected facilities will be below the WEC emissions thresholds. To 
further support the overall goal of reducing methane emissions, CAA 
section 136(a) and (b) also provides $1.55 billion to, among other 
things, help finance the early adoption of emissions reduction 
methodologies and technologies and to support monitoring of methane 
emissions. More detailed background information on the impacts of 
methane on public health and welfare and the related regulatory 
activities is provided in section I.C.1. of this preamble.
1. How does methane affect public health and welfare?
    Elevated concentrations of greenhouse gases (GHGs) including 
methane have been warming the planet, leading to changes in the Earth's 
climate that are occurring at a pace and in a way that threatens human 
health, society, and the natural environment. While the EPA is not 
statutorily required to make any particular scientific or factual 
findings regarding the impact of GHG emissions on public health and 
welfare in support of the proposed WEC, the EPA is providing in this 
section a brief scientific background on methane and climate change to 
offer additional context for this rulemaking and to help the public 
understand the environmental impacts of GHGs such as methane.
    As a GHG, methane in the atmosphere absorbs terrestrial infrared 
radiation, which in turn contributes to increased global warming and 
continuing climate change, including increases in air and ocean 
temperatures, changes in precipitation patterns, retreating snow and 
ice, increasingly severe weather events, such as hurricanes of greater 
intensity, and sea level rise, among other impacts. Methane also 
contributes to climate change through chemical reactions in the 
atmosphere that produce tropospheric ozone and stratospheric water 
vapor. In 2022, atmospheric concentrations of methane increased by 
nearly 17 parts per billion (ppb) over 2021 levels to reach 1,912 
ppb.\9\ This was the largest increase since the start of the NOAA 
atmospheric record in 1984, with current concentrations now more than 
two and a half times larger than the preindustrial level.\10\ Methane 
is responsible for about one third of all warming resulting from human 
emissions of well-mixed GHGs,\11\ and due to its high radiative 
efficiency compared to carbon dioxide, methane mitigation is one of the 
best opportunities for reducing near-term warming.
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    \9\ NOAA, https://gml.noaa.gov/webdata/ccgg/trends/ch4/ch4_annmean_gl.txt.
    \10\ Blunden, J. and T. Boyer, Eds., 2022: ``State of the 
Climate in 2021.'' Bull. Amer. Meteor. Soc., 103 (8), Si-S465, 
https://doi.org/10.1175/2022BAMSStateoftheClimate.1, 103 (8), Si-
S465, https://doi.org/10.1175/2022BAMSStateoftheClimate.1.
    \11\ IPCC, 2021: Summary for Policymakers. In: Climate Change 
2021: The Physical Science Basis. Contribution of Working Group I to 
the Sixth Assessment Report of the Intergovernmental Panel on 
Climate Change [Masson-Delmotte, V., P. Zhai, A. Pirani, S.L. 
Connors, C. P[eacute]an, S. Berger, N. Caud, Y. Chen, L. Goldfarb, 
M.I. Gomis, M. Huang, K. Leitzell, E. Lonnoy, J.B.R. Matthews, T.K. 
Maycock, T. Waterfield, O. Yelek[ccedil]i, R. Yu, and B. Zhou 
(eds.)]. Cambridge University Press, Cambridge, United Kingdom and 
New York, NY, USA, pp. 3-32, doi:10.1017/9781009157896.001.
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    Major scientific assessments continue to be released that further 
advance our understanding of the climate system and the impacts that 
methane and other GHGs have on public health and welfare both for 
current and future generations. According to the Intergovernmental 
Panel on Climate Change (IPCC) Sixth Assessment Report, ``it is 
unequivocal that human influence has warmed the atmosphere, ocean and 
land. Widespread and rapid changes in the atmosphere, ocean, cryosphere 
and biosphere have occurred.'' \12\ Recent EPA modeling efforts \13\ 
have also shown that impacts from these changes are projected to vary 
regionally within the U.S. For example, large damages are projected 
from sea level rise in the Southeast, wildfire smoke in the Western 
U.S., and impacts to agricultural crops and rail and road 
infrastructure in the Northern Plains. Scientific assessments, EPA 
analyses, and updated observations and projections document the rapid 
rate of current and future climate change and the potential range 
impacts both

[[Page 5322]]

globally and in the United States,\14\ presenting clear support 
regarding the current and future dangers of climate change and the 
importance of GHG emissions mitigation.
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    \12\ Id.
    \13\ (1) EPA. 2021. Technical Documentation on the Framework for 
Evaluating Damages and Impacts (FrEDI). U.S. Environmental 
Protection Agency, EPA 430-R-21-004.
    (2) Hartin C., E.E. McDuffie, K. Novia, M. Sarofim, B. Parthum, 
J. Martinich, S. Barr, J. Neumann, J. Willwerth, & A. Fawcett. 
Advancing the estimation of future climate impacts within the United 
States. EGUsphere doi: 10.5194/egusphere-2023-114, 2023.
    \14\ (1) USGCRP, 2018: Impacts, Risks, and Adaptation in the 
United States: Fourth National Climate Assessment, Volume II 
[Reidmiller, D.R., C.W. Avery, D.R. Easterling, K.E. Kunkel, K.L.M. 
Lewis, T.K. Maycock, and B.C. Stewart (eds.)]. U.S. Global Change 
Research Program, Washington, DC, USA, 1515 pp. doi: 10.7930/
NCA4.2018. Available at https://nca2018.globalchange.gov.
    (2) IPCC, 2021: Summary for Policymakers. In: Climate Change 
2021: The Physical Science Basis. Contribution of Working Group I to 
the Sixth Assessment Report of the Intergovernmental Panel on 
Climate Change [Masson-Delmotte, V., P. Zhai, A. Pirani, S.L. 
Connors, C. P[eacute]an, S. Berger, N. Caud, Y. Chen, L. Goldfarb, 
M.I. Gomis, M. Huang, K. Leitzell, E. Lonnoy, J.B.R. Matthews, T.K. 
Maycock, T. Waterfield, O. Yelek[ccedil]i, R. Yu and B. Zhou 
(eds.)]. Cambridge University Press.
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2. Related Actions
    As mandated by CAA section 136(c) and (d), the applicability of the 
WEC is based upon the quantity of metric tons of CO2e 
emitted per year pursuant to the requirements of subpart W. Further, 
CAA section 136(e) requires that the WEC amount be calculated based 
upon methane emissions reported pursuant to subpart W. As a result, 
this proposed action builds upon previous subpart W rulemakings.
    On August 1, 2023, the EPA proposed revisions to subpart W 
consistent with the authority and directives set forth in CAA section 
136(h) as well as the EPA's authority under CAA section 114 (88 FR 
50282) (hereafter referred to as the ``2023 Subpart W Proposal''). In 
that rulemaking, the EPA proposed revisions to require reporting of 
additional emissions or emissions sources to address potential gaps in 
the total methane emissions reported by facilities to subpart W. For 
example, these proposed revisions would add a new emissions source, 
referred to as ``other large release events,'' to capture large 
emission events that are not accurately accounted for using existing 
methods in subpart W. The EPA also proposed revisions to add or revise 
existing calculation methodologies to improve the accuracy of reported 
emissions, incorporate additional empirical data, and allow owners and 
operators of applicable facilities to submit empirical emissions data 
that could appropriately demonstrate the extent to which a charge is 
owed in implementation of CAA section 136, as directed by CAA section 
136(h). The EPA also proposed revisions to existing reporting 
requirements to collect data that would improve verification of 
reported data, ensure accurate reporting of emissions, and improve the 
transparency of reported data. For clarity of discussion within this 
preamble, unless otherwise stated, references to provisions of subpart 
W (i.e., 40 CFR 98.230 through 98.238) reflect the language as proposed 
in the 2023 Subpart W Proposal. The EPA's intention in this proposed 
rulemaking is that the final WEC rule would update the proposed cross-
references to subpart W to be consistent with the final Subpart W rule 
resulting from the 2023 Subpart W Proposal.
    Under the Greenhouse Gas Reporting Program, the EPA also recently 
issued a supplemental proposal to a 2022 proposed rule (88 FR 32852, 
May 22, 2023), which included proposed updates to the General 
Provisions of the Greenhouse Gas Reporting Rule to reflect revised 
global warming potentials (GWPs), proposed reporting of GHG data from 
additional sectors (i.e., non-subpart W sectors), and proposed 
revisions to source categories other than subpart W that would improve 
implementation of the Greenhouse Gas Reporting Rule. The proposed 
revision to the GWP of methane (from 25 to 28) is expected to lead to a 
small increase in the number of facilities that exceed the subpart W 
25,000 mt CO2e threshold and thus become subject to the 
proposed part 99 requirements. This supplemental proposed rule is not 
expected to otherwise impact subpart W reporting requirements as they 
pertain to the applicability or implementation of the proposed part 99 
requirements.
    In addition, on November 15, 2021 (86 FR 63110), the EPA proposed 
under CAA section 111(b) standards of performance regulating emissions 
of methane and volatile organic compounds (VOCs) for certain new, 
reconstructed, and modified sources in the oil and natural gas source 
category (proposed as 40 CFR part 60, subpart OOOOb) (hereafter 
referred to as ``NSPS OOOOb''), as well as emissions guidelines 
regulating emissions of methane under CAA section 111(d) for certain 
existing oil and natural gas sources (proposed as 40 CFR part 60, 
subpart OOOOc) (hereafter referred to as ``EG OOOOc''). The November 
15, 2021 proposal (covering both NSPS OOOOb and EG OOOOc)--and which 
Congress explicitly referred to in section 136--will be referred to 
hereafter as the ``NSPS OOOOb/EG OOOOc 2021 Proposal.'' The NSPS OOOOb/
EG OOOOc 2021 Proposal sought to strengthen standards of performance 
previously in effect under section 111(b) of the CAA for new, modified 
and reconstructed oil and natural gas sources, and to establish 
emissions guidelines under section 111(d) of the CAA for states to 
follow in developing plans to limit methane emissions from existing oil 
and natural gas sources.
    On December 6, 2022, the EPA issued a supplemental proposal to 
update, strengthen and expand upon the NSPS OOOOb/EG OOOOc 2021 
Proposal (87 FR 74702). The December 6, 2022 supplemental proposal will 
be referred to hereafter as ``NSPS OOOOb/EG OOOOc 2022 Supplemental 
Proposal.'' This supplemental proposal modified certain standards 
proposed in the NSPS OOOOb/EG OOOOc 2021 Proposal and added proposed 
requirements for sources not previously covered. Among other things, 
the supplemental proposal sought to: ensure that all well sites are 
routinely monitored for leaks, with requirements based on the type and 
amount of equipment on site; encourage the deployment of innovative and 
advanced monitoring technologies by establishing performance 
requirements that can be met by a broader array of technologies; 
prevent leaks from abandoned and unplugged wells by requiring 
documentation that well sites are properly shut-in and plugged before 
monitoring is allowed to end; leverage qualified expert monitoring to 
identify ``super-emitters'' for prompt mitigation; and strengthen 
requirements for flares.
    On December 2, 2023, in an action titled, ``Standards of 
Performance for New, Reconstructed, and Modified Sources and Emissions 
Guidelines for Existing Sources: Oil and Natural Gas Sector Climate 
Review,'' the EPA finalized these two rules to reduce air emissions 
from the Crude Oil and Natural Gas source category under section 111 of 
the Clean Air Act. First, the EPA finalized NSPS OOOOb regulating GHG 
(in the form of a limitation on emissions of methane) and VOCs 
emissions for the Crude Oil and Natural Gas source category pursuant to 
CAA section 111(b)(1)(B) (hereafter, ``NSPS OOOOb''). Second, the EPA 
finalized presumptive standards in EG OOOOc to limit GHG emissions (in 
the form of methane limitations) from designated facilities in the 
Crude Oil and Natural Gas source category, as well as requirements 
under the CAA section 111(d) for states to follow in developing, 
submitting, and implementing state plans to establish performance 
standards (hereafter, ``EG OOOOc'').\15\
---------------------------------------------------------------------------

    \15\ In this action, the EPA also finalized several related 
actions stemming from the joint resolution of Congress, adopted on 
June 30, 2021, under the CRA, disapproving the 2020 Policy Rule, and 
also finalized a protocol under the general provisions for use of 
Optical Gas Imaging.
---------------------------------------------------------------------------

    The NSPS OOOOb/EG OOOOc 2021 Proposal and Final NSPS OOOOb/EG OOOOc 
are relevant to this WEC

[[Page 5323]]

proposal in two ways: first, WEC applicable facilities containing CAA 
section 111(b) and (d) facilities that are in compliance with the 
applicable standards are likely to have emissions below the thresholds 
specified in section II.B. of this preamble due to mitigation resulting 
from meeting the methane emissions requirements of NSPS OOOOb or EG 
OOOOc-implementing state and Federal plans, and therefore would not be 
expected to incur charges under the WEC program; and second, compliance 
with applicable standards (if certain criteria are met) may exempt 
facilities from the WEC under the regulatory compliance exemption 
outlined at CAA section 136(f)(6) (discussed in section II.D.2. of this 
preamble). As a part of the NSPS OOOOb/EG OOOOc 2022 Supplemental 
Proposal, the EPA requested comment on the criteria and approaches that 
the Administrator should consider in making the CAA section 
136(f)(6)(A)(ii) equivalency determination, which is discussed at 
section II.D.2. of this preamble.
    The EPA also opened a non-regulatory docket on November 4, 2022 and 
issued a Request for Information (RFI) seeking public input to inform 
program design related to CAA section 136.\16\ As part of this request, 
the EPA sought input on issues that should be considered related to 
implementation of the WEC. The comment period closed on January 18, 
2023.
---------------------------------------------------------------------------

    \16\ Docket ID No. EPA-HQ-OAR-2022-0875.
---------------------------------------------------------------------------

    The 2023 Subpart W Proposal, the NSPS OOOOb/EG OOOOc 2021 Proposal, 
the NSPS OOOOb/EG OOOOc 2022 Supplemental Proposal, and the November 
2022 request for information are relevant to this proposal. While the 
EPA has reviewed or will review relevant comments submitted as part of 
the rulemaking actions and request for information, the EPA is not 
obligated to respond to those comments in this action since the comment 
solicitations did not accompany a proposal regarding the WEC. 
Commenters who would like the EPA to formally consider in this 
rulemaking any relevant comments previously submitted must resubmit 
those comments to the EPA during this proposal's comment period.
    In addition to the WEC requirement, and the related revisions to 
subpart W to facilitate accuracy of reporting and charge calculation, 
as noted in section I.C. of this preamble, CAA sections 136(a) and (b) 
provide $1.55 billion for the Methane Emissions Reduction Program, 
including for incentives for methane mitigation and monitoring. The EPA 
is partnering with the U.S. Department of Energy and National Energy 
Technology Laboratory to provide financial assistance for monitoring 
and reducing methane emissions from the oil and gas sector, as well as 
technical assistance to help implement solutions for monitoring and 
reducing methane emissions. As designed by Congress, these incentives 
were intended to complement the regulatory programs and to help 
facilitate the transition to a more efficient petroleum and natural gas 
industry.

D. Legal Authority

    The EPA is proposing this rule under its newly established 
authority provided in CAA section 136. As noted in section I.B. of this 
preamble, the IRA added CAA section 136, ``Methane Emissions and Waste 
Reduction Incentive Program for Petroleum and Natural Gas Systems,'' 
which requires that the EPA impose and collect an annual specified 
charge on methane emissions that exceed an applicable waste emissions 
threshold from an owner or operator of an applicable facility that 
reports more than 25,000 mt CO2e of greenhouse gases emitted 
per year pursuant to subpart W of the GHGRP. Under CAA section 136, an 
``applicable facility'' is a facility within nine of the ten industry 
segments subject to subpart W, as currently defined in 40 CFR 98.230 
(excluding natural gas distribution).
    The EPA is also proposing elements of this rule under its existing 
CAA authority provided in CAA section 114, as well as CAA section 301. 
CAA section 114(a)(1) authorizes the Administrator to require emissions 
sources, persons subject to the CAA, or persons whom the Administrator 
believes may have necessary information to monitor and report emissions 
and provide other information the Administrator requests for the 
purposes of carrying out any provision of the CAA (except for a 
provision of title II with respect to manufacturers of new motor 
vehicles or new motor vehicle engines). Thus, CAA section 114(a)(1) 
additionally provides the EPA broad authority to require the 
information that would be required by this proposed rule because the 
information is relevant for carrying out CAA section 136. Additionally, 
CAA section 301(a)(1) provides that the EPA is authorized to prescribe 
such regulations ``as are necessary to carry out [its] functions under 
[the CAA].''
    The Administrator has determined that this action is subject to the 
provisions of section 307(d) of the CAA. Section 307(d) contains a set 
of procedures relating to the issuance and review of certain CAA rules.
    In addition, pursuant to sections 114, 301, and 307 of the CAA, the 
EPA is publishing proposed confidentiality determinations for the new 
data elements required by this proposed regulation.

II. Requirements To Implement the Waste Emissions Charge

    This section summarizes the EPA's proposed approach to calculating 
WEC, including how WEC would be calculated at the facility level, how 
netting of emissions from facilities under common ownership or control 
would be applied, the EPA's interpretation of common ownership or 
control, and how the exemptions established in CAA section 136(f) would 
be implemented.

A. Proposed Definitions To Support WEC Implementation

    In accordance with CAA section 136(d), applicable facilities under 
part 99 are those facilities within certain industry segments as 
defined under part 98, subpart W. Thus, we are proposing several 
definitions within the general provisions of 40 CFR 99.2. First, as the 
statute specifies, we are proposing a definition of ``applicable 
facility'' to mean a facility within one or more of the following 
industry segments: onshore petroleum and natural gas production, 
offshore petroleum and natural gas production, onshore petroleum and 
natural gas gathering and boosting, onshore natural gas processing, 
onshore natural gas transmission compression, onshore natural gas 
transmission pipeline, underground natural gas storage, LNG import and 
export equipment, or LNG storage, as those industry segments are 
defined in 40 CFR 98.230 of subpart W.\17\ A single reporting facility 
under part 98, subpart W, typically consists of operations within a 
single industry segment. However, for certain industry segments a 
single reporting facility may represent operations in two or more 
industry segments. Industry segments that potentially may exist within 
the same reporting facility are onshore natural gas processing, onshore 
natural gas transmission compression, underground natural gas storage, 
LNG import and export equipment, and LNG storage. To accommodate for 
such facilities, we are proposing within the definition of ``applicable 
facility'' that such operations would be considered a single applicable 
facility under part 99.
---------------------------------------------------------------------------

    \17\ See 42 U.S.C. 7436(d).

---------------------------------------------------------------------------

[[Page 5324]]

    We are also proposing a definition of ``WEC applicable facility'' 
in 40 CFR 99.2, which would mean an applicable facility for which the 
owner or operator of the subpart W reporting facility reported GHG 
emissions under subpart W of more than 25,000 mt CO2e--the 
amount set in the statute. In cases where a subpart W facility reports 
under two or more of the industry segments listed in the previous 
paragraph, the EPA proposes that the 25,000 mt CO2e 
threshold would be evaluated based on the total facility GHG emissions 
reported to subpart W across all of the industry segments (i.e., the 
facility's total subpart W GHGs). As discussed in section II.B.1. of 
this preamble, the waste emissions threshold is the facility-specific 
threshold, based upon an industry segment-specific methane intensity 
threshold, above which the EPA must impose and collect the WEC. For the 
purposes of determining the waste emissions threshold for a WEC 
applicable facility that operates within multiple industry segments, 
the EPA proposes that each industry segment would be assessed 
separately (i.e., using industry segment-specific throughput and 
methane intensity threshold) and then summed together to determine the 
waste emissions threshold for the facility. The EPA proposes that this 
approach would be used in all cases where a WEC applicable facility 
contains equipment in multiple subpart W industry segments.
    The EPA requests comment on an alternative definition of WEC 
applicable facility as it applies to subpart W facilities that report 
under two or more industry segments. This alternative approach would 
assess these facilities against the 25,000 mt CO2e 
applicability threshold using the CO2e reported under 
subpart W for each individual segment at the facility rather than the 
total facility subpart W CO2e reported across all segments. 
CAA section 136(d) defines an applicable facility as one ``within'' the 
nine industry segments subject to the WEC and does not specify that an 
applicable facility is in one and only one industry segment. The EPA 
understands this to mean that an applicable facility constitutes an 
entire subpart W facility, including those that report under more than 
one segment. Thus, based on the statutory text, the EPA proposes to 
assess WEC applicability based on the entire subpart W facility's 
emissions. Based on historic subpart W data, no more than two dozen 
facilities report data for multiple segments, and when total subpart W 
CO2e is summed across all segments at these facilities, 
almost all of these facilities remain below the 25,000 mt 
CO2e threshold. Historic data also show that the industry 
segments (onshore natural gas processing, onshore natural gas 
transmission compression, and underground natural gas storage) located 
at these facilities generally have methane emissions below the waste 
emissions thresholds. The proposed approach of using total subpart W 
facility CO2e for determining WEC applicability therefore 
would not result in a significant number of facilities being regulated 
under WEC compared to an approach that assessed applicability using 
subpart W CO2e for each individual industry segment at a 
facility. Based on historic data, the EPA does not expect the very 
small number of facilities with operations in multiple subpart W 
segments that could be subject to the WEC under the proposed approach 
to experience a substantially different financial impact under the 
alternative approach.
    We are also proposing a definition for ``WEC applicable emissions'' 
in 40 CFR 99.2, which would mean the annual methane emissions, as 
calculated using equations specified in part 99, from a WEC applicable 
facility that are either equal to, below, or exceeding the waste 
emissions threshold for the facility after consideration of any 
applicable exemptions. The proposed calculation methodology for WEC 
applicable emissions is addressed in section II.B.2. of this preamble. 
We are also proposing a definition for ``facility applicable 
emissions'' in 40 CFR 99.2 which would mean the annual methane 
emissions, as calculated using equations specified in part 99, from a 
WEC applicable facility that are either equal to, below, or exceeding 
the waste emissions threshold for the facility prior to consideration 
of any applicable exemptions.
    The proposed provisions of this part would apply to WEC obligated 
parties and WEC applicable facilities. In addition to the proposed 
definition for WEC applicable facility discussed earlier in this 
section, we are proposing a definition for the term WEC obligated party 
in 40 CFR 99.2. The term WEC obligated party refers to the owners or 
operators of one or more WEC applicable facilities. For WEC applicable 
facilities that have more than one owner or operator, we are proposing 
that the WEC obligated party is an owner or operator selected by a 
binding agreement among the owners and operators of the WEC applicable 
facility. The EPA anticipates that such an agreement would be similar 
to those used in carrying out 40 CFR 98.4(b) under the GHGRP.
    For the purposes of submitting the WEC filing, we are proposing 
that the WEC obligated party's WEC applicable facilities are the WEC 
applicable facilities for which it is the owner or operator (including 
through binding agreement as noted above), as of December 31 of each 
reporting year. Under the proposed approach, the WEC obligated party 
would be responsible for any WEC obligation from facilities for which 
it was the facility owner or operator as of December 31 of the 
reporting year. The EPA recognizes that facilities may be acquired or 
divested at any time in the year, and that under the proposed approach 
the year-end owner or operator would be responsible for data and any 
corresponding WEC obligation for the entire reporting year. The EPA 
believes that this approach is both reasonable and necessary for 
implementation of the WEC program. First, subpart W data reporting uses 
the same approach; the facility owner or operator as of December 31 is 
responsible for emissions for the entire year. Because the subpart W 
data is inextricably linked to the WEC filing, it would be 
inappropriate to have different facility owners or operators under each 
regulation. Specifically, different owners or operators for the same 
facility under subpart W and the WEC program could lead to challenges 
for WEC filings and associated data verification, and increase industry 
burden by requiring significant coordination between different 
companies. Second, subpart W data are reported on an annual basis, and 
there is no means by which methane emissions could be accurately 
allocated across multiple owners or operators in a single year. For 
example, emissions could not be pro-rated based on time of ownership 
over the reporting year because emissions do not occur uniformly over 
time, and emissions from certain sources cannot be linked to specific 
times. Similarly, there is not a direct relationship between methane 
emissions and oil and natural gas production, so temporal data on 
hydrocarbon production could not be used to accurately allocate 
emissions. The EPA therefore believes it would be neither practical nor 
accurate for the reporting responsibility and potential WEC obligation 
for a single facility to be split among multiple WEC obligated parties.
    The EPA also recognizes that a facility's owner or operator, and 
thus its WEC obligated party, may change between December 31 and March 
31. In such situations, under the proposed approach the WEC obligated 
party associated with a facility as of December

[[Page 5325]]

31 would remain responsible for accounting for that facility in its WEC 
filing and be responsible for any WEC obligation associated with that 
facility.
    The EPA invites comments on these proposed definitions and whether 
additional definitions would help with the implementation of the WEC. 
The EPA requests comment on the proposed definition of WEC obligated 
party being responsible for all facilities for which it was the 
facility owner or operator as of December 31, regardless of when in the 
reporting year it became a facility's owner or operator. The EPA 
requests comment on alternative definitions of WEC obligated party, 
including those that would allocate facility subpart W data to multiple 
WEC obligated parties and a definition that would place the WEC 
obligation and reporting requirements on the WEC obligated party that 
was a facility's owner or operator at the time of the WEC filing (i.e., 
as of March 31 of the year following the reporting year rather than 
December 31 of the reporting year). For alternative definitions that 
would allocate subpart W data, the EPA requests comment on potential 
methodologies that would accurately split the annual subpart W data 
across multiple WEC obligated parties.

B. Waste Emissions Thresholds

    The CAA establishes a waste emissions threshold that is defined in 
terms of industry segment-specific methane intensity thresholds 
applicable to certain facilities that report GHG emissions under 
subpart W of the GHGRP. The industry segment-specific methane intensity 
thresholds specified in CAA 136(f) and listed in Table 2 of this 
preamble are based on a rate of methane emissions per amount of natural 
gas or oil sent to sale from or through a facility. The industry 
segment-specific methane intensity thresholds are generally defined in 
terms of a percentage of throughput (e.g., 0.002 percent of natural gas 
sent to sale). However, since the WEC is based on metric tons of 
methane (e.g., $900/metric ton) that exceed the threshold, for the 
purposes of calculating the number of metric tons that are subject to 
the WEC, we are proposing to calculate the facility waste emissions 
thresholds in metric tons of methane.
    For the onshore and offshore petroleum and natural gas production 
industry segments, CAA section 136(f) differentiates based on whether 
the facility is sending natural gas to sale or only sending oil to 
sale, and if the facility does not send natural gas to sale, the 
threshold is based on methane emissions per amount of oil sent to sale. 
For facilities that are not in the onshore or offshore production 
industry segments, the industry segment-specific methane intensity 
thresholds are based on the amount of natural gas sent to sale from or 
through the facility. The industry segment-specific methane intensity 
thresholds are applied to the natural gas or petroleum throughput 
attributable to that industry segment to calculate facility-specific 
waste emissions thresholds. See Table 2 for an overview of how the 
waste emissions thresholds are calculated. Facility waste emissions 
thresholds are compared to reported methane emissions; facilities with 
methane emissions that exceed the waste emissions threshold may be 
subject to the WEC. For WEC applicable facilities under common 
ownership or control of a single WEC obligated party, the WEC 
applicable emissions for each facility are summed to calculate the net 
emissions for that WEC obligated party.
    Subpart W requires reporting of natural gas throughput by thousand 
standard cubic feet, oil by barrels, and methane by metric ton. As a 
practical matter, since the WEC is based on a dollar per metric ton of 
methane, the waste emissions thresholds must generally be converted 
into metric tons of methane for comparison against reported methane, 
generally by multiplying the thresholds by the density of methane.

  Table 2--Industry Segment Throughput Metrics and Methane Intensities
------------------------------------------------------------------------
                                                        Industry segment-
       Industry segment          Throughput metric \a\  specific methane
                                                            intensity
------------------------------------------------------------------------
Onshore petroleum and natural   The quantity of         0.20 percent of
 gas production.                 natural gas produced    natural gas
Offshore petroleum and natural   from producing wells    sent to sale
 gas production.                 that is sent to sale    from facility;
                                 in the calendar year,   or 10 metric
                                 in thousand standard    tons of methane
                                 cubic feet; or the      per million
                                 quantity of crude oil   barrels of oil
                                 produced from           sent to sale
                                 producing wells that    from facility,
                                 is sent to sale in      if facility
                                 the calendar year, in   sends no
                                 barrels, if facility    natural gas to
                                 sends no natural gas    sale.
                                 to sale.
Onshore petroleum and natural   The quantity of         0.05 percent of
 gas gathering and boosting.     natural gas             natural gas
                                 transported through     sent to sale
                                 the facility to a       from or through
                                 downstream endpoint     facility.
                                 such as a natural gas
                                 processing facility,
                                 a natural gas
                                 transmission
                                 pipeline, a natural
                                 gas distribution
                                 pipeline, a storage
                                 facility, or another
                                 gathering and
                                 boosting facility in
                                 the calendar year, in
                                 thousand standard
                                 cubic feet.
Onshore natural gas processing  The quantity of         ................
                                 residue gas leaving
                                 that has been
                                 processed by the
                                 facility and any gas
                                 that passes through
                                 the facility to sale
                                 without being
                                 processed by the
                                 facility in the
                                 calendar year, in
                                 thousand standard
                                 cubic feet.
Onshore natural gas             The quantity of         0.11 percent of
 transmission compression.       natural gas             natural gas
                                 transported through     sent to sale
                                 the compressor          from or through
                                 station in the          facility.
                                 calendar year, in
                                 thousand standard
                                 cubic feet.
Onshore natural gas             The quantity of         ................
 transmission pipeline.          natural gas
                                 transported through
                                 the facility and
                                 transferred to third
                                 parties such as LDCs
                                 or other transmission
                                 pipelines in the
                                 calendar year, in
                                 thousand standard
                                 cubic feet.
Underground natural gas         The quantity of         ................
 storage.                        natural gas withdrawn
                                 from storage and sent
                                 to sale in the
                                 calendar year, in
                                 thousand standard
                                 cubic feet.
LNG import and export           For LNG import          0.05 percent of
 equipment.                      equipment, the          natural gas
                                 quantity of LNG         sent to sale
                                 imported that is sent   from or through
                                 to sale in the          facility.
                                 calendar year, in
                                 thousand standard
                                 cubic feet; for LNG
                                 export equipment, the
                                 quantity of LNG
                                 exported that is sent
                                 to sale in the
                                 calendar year, in
                                 thousand standard
                                 cubic feet.
LNG storage...................  The quantity of LNG     ................
                                 withdrawn from
                                 storage and sent to
                                 sale in the calendar
                                 year, in thousand
                                 standard cubic feet.
------------------------------------------------------------------------
\a\ Throughput metrics in this table are based on the proposed subpart W
  reporting elements in the 2023 Subpart W Proposal (88 FR 50282).

1. Facility Waste Emissions Thresholds
    CAA section 136(f)(1) through (3) establishes facility-specific 
waste emissions thresholds above which the EPA must impose and collect 
the WEC. The CAA defines waste emissions threshold requirements, and 
establishes the method for calculation of the charge,

[[Page 5326]]

for nine segments of the oil and gas industry.
    CAA section 136(f)(1) requires the EPA to impose and collect the 
WEC on facilities in the onshore petroleum and natural gas production 
and offshore petroleum and natural gas production industry segments 
with methane emissions, in metric tons, that exceed either 0.20 percent 
of the natural gas sent to sale from the facility or, if no natural gas 
is sent to sale, 10 metric tons of methane per million barrels of oil 
sent to sale from the facility. To determine the waste emissions 
threshold from a WEC applicable facility in the onshore petroleum and 
natural gas production and the offshore petroleum and natural gas 
production industry segments, the EPA is proposing two equations based 
on whether the facility sends natural gas to sale, which reflect the 
statutory text at 136(f)(1)(A) and (B). For onshore and offshore 
petroleum and natural gas production WEC applicable facilities that 
send natural gas to sale, we are proposing to use equation B-1 of 40 
CFR 99.20(a). This equation multiplies the annual quantity of natural 
gas sent to sale from a WEC applicable facility by 0.002 (i.e., 0.20 
percent) and the density of methane (0.0192 metric tons per thousand 
standard cubic feet).\18\ For onshore and offshore petroleum and 
natural gas production facilities that have no natural gas sent to 
sale, we are proposing to use equation B-2 of 40 CFR 99.20(b). Similar 
to proposed equation B-2, the annual quantity of oil sent to sale from 
a WEC applicable facility would be multiplied by 10 metric tons of 
methane per million barrels of oil.\19\
---------------------------------------------------------------------------

    \18\ Equation B-1 reflects the statutory text at 136(f)(1)(A), 
which states: ``With respect to imposing and collecting the charge 
under subsection (c) for an applicable facility [in the onshore 
petroleum and natural gas production and offshore petroleum and 
natural gas production industry segments], the Administrator shall 
impose and collect the charge on the reported metric tons of methane 
emissions from such facility that exceed (A) 0.20 percent of the 
natural gas sent to sale from such facility . . .'' 42 U.S.C. 
7436(f)(1)(A).
    \19\ Equation B-2 reflects the statutory text at 136(f)(1)(B), 
which states: ``With respect to imposing and collecting the charge 
under subsection (c) for an applicable facility [in the onshore 
petroleum and natural gas production and offshore petroleum and 
natural gas production industry segments], the Administrator shall 
impose and collect the charge on the reported metric tons of methane 
emissions from such facility that exceed . . . (B) 10 metric tons of 
methane per million barrels of oil sent to sale from such facility, 
if such facility sent no natural gas to sale.'' 42 U.S.C. 
7436(f)(1)(B).
---------------------------------------------------------------------------

    For WEC applicable facilities in the onshore petroleum and natural 
gas gathering and boosting, onshore natural gas processing, LNG import 
and export equipment, and LNG storage industry segments, CAA section 
136(f)(2) requires the EPA to impose and collect WEC on facilities with 
reported methane emissions, in metric tons, that exceed 0.05 percent of 
the natural gas sent to sale from or through such facility. To 
determine the waste emissions threshold from a WEC applicable facility 
in these industry segments, we are proposing to use equation B-3 under 
40 CFR 99.20(c). This equation would multiply the annual quantity of 
natural gas sent to sale from or through a WEC applicable facility by 
0.0005 (i.e., 0.05 percent) and the density of methane (0.0192 metric 
tons per thousand standard cubic feet) to determine the facility-level 
waste emissions threshold.\20\ The EPA notes that certain facilities in 
the gathering and boosting and natural gas processing industry segments 
may have zero throughput values using the proposed approach, because 
these facilities either receive no natural gas, or process or dispose 
of natural gas received, in a manner that results in sending zero 
quantities of natural gas to sale. Treatment of these facilities is 
discussed in section II.B.6. of this preamble.
---------------------------------------------------------------------------

    \20\ Equation B-3 reflects the statutory text at 136(f)(2), 
which states: ``With respect to imposing and collecting the charge 
under subsection (c) for an applicable facility in [the onshore 
petroleum and natural gas gathering and boosting, onshore natural 
gas processing, LNG import and export equipment, and LNG storage 
industry segments], the Administrator shall impose and collect the 
charge on the reported metric tons of methane emissions that exceed 
0.05 percent of the natural gas sent to sale from or through such 
facility.'' 42 U.S.C. 7436(f)(2).
---------------------------------------------------------------------------

    CAA section 136(f)(3) requires the EPA to impose and collect WEC on 
WEC applicable facilities in the onshore natural gas transmission 
compression, onshore natural gas transmission pipeline, and underground 
natural gas storage industry segments with methane emissions, in metric 
tons, that exceed 0.11 percent of the natural gas sent to sale from or 
through such facility. We are proposing that equation B-4 under 40 CFR 
99.20(d) be used to calculate the waste emissions threshold from a WEC 
applicable facility in these industry segments. Using proposed equation 
B-4 the EPA would multiply the annual quantity of natural gas sent to 
sale from or through a WEC applicable facility by 0.0011 (i.e., 0.11 
percent) and the density of methane (0.0192 metric tons per thousand 
standard cubic feet) to determine the facility-level waste emissions 
threshold.\21\
---------------------------------------------------------------------------

    \21\ Equation B-4 reflects the statutory text at 136(f)(3), 
which states: ``With respect to imposing and collecting the charge 
under subsection (c) for an applicable facility in [the onshore 
natural gas transmission compression, onshore natural gas 
transmission pipeline, and underground natural gas storage industry 
segments], the Administrator shall impose and collect the charge on 
the reported metric tons of methane emissions that exceed 0.11 
percent of the natural gas sent to sale from or through such 
facility.'' 42 U.S.C. 7436(f)(3).
---------------------------------------------------------------------------

    The annual quantity of natural gas sent to sale from or through a 
facility reported under subpart W is reported in units of thousand 
standard cubic feet of natural gas per year, while facility methane 
emissions are reported in metric tons. The EPA is proposing to 
interpret the industry segment-specific methane intensity thresholds 
(i.e., 0.20 percent, 0.05 percent, and 0.11 percent) indicated in CAA 
section 136(f)(1) through (3) to be in units of thousand standard cubic 
feet of methane of emissions per thousand standard cubic feet of 
natural gas. This requires reconciliation of methane emissions reported 
on mass basis and throughput reported on a volumetric basis. Because 
the waste emission charge is assessed using dollars per metric ton, the 
amount by which a facility is below or exceeding the waste emissions 
threshold must ultimately be converted to metric tons. The EPA's 
proposed approach in equations B-1, B-3, and B-4 calculates facility 
waste emissions thresholds in metric tons by calculating the volume of 
gas at the given industry segment-specific methane intensity and then 
calculating what the mass of that volume would be if it were methane by 
multiplying by the density of methane (0.0192 metric tons per thousand 
standard cubic feet at standard temperature and pressure of 60 [deg]F 
and 14.7 psia). This allows the waste emissions threshold to be 
directly compared to reported metric tons of methane. The proposed 
approach is mathematically equivalent to, but simpler than, an approach 
that would convert reported methane emissions to volume, subtract a 
volumetric waste emissions threshold from that reported volume, and 
then convert the resulting value back to metric tons methane. The EPA 
notes that the proposed approach does not require information on the 
constituents or density of natural gas throughput.
    As described in this section of the preamble, we are proposing to 
calculate waste emissions thresholds at the facility level, using the 
industry segment-specific methane intensity threshold given in CAA 
sections 136(f)(1) through (3), and the industry segment throughput 
reported under part 98, subpart W. The vast majority of facilities 
report as a single subpart W facility to a single subpart W industry 
segment. However, as discussed in section II.A. of this preamble, there 
are

[[Page 5327]]

a small number of reporters that report as a single subpart W facility 
to multiple subpart W industry segments. Specifically, for facilities 
that report to multiple industry segments under a single subpart W 
facility, we are proposing in 40 CFR 99.20(e) that the facility-level 
waste emissions threshold is determined as the sum of the waste 
emissions thresholds for each industry segment that the facility 
operates within.
    The EPA proposes to interpret ``natural gas sent to sale'' to mean 
the amount of natural gas sent to sale from a facility in the onshore 
or offshore petroleum and natural gas industry segments, as reported 
under subpart W. The EPA proposes to interpret ``natural gas sent to 
sale from or through'' to mean the natural gas throughput volume for a 
facility not in the onshore or offshore petroleum and natural gas 
industry segments that aligns with the movement of gas through a 
facility (e.g., gas transported rather than gas received), as reported 
under subpart W. For facilities in the onshore and offshore petroleum 
and natural gas production industry segments that do not send natural 
gas to sale, the EPA proposes to interpret ``barrels of oil sent to 
sale'' to mean the quantity of crude oil sent to sale, as reported 
under subpart W. The EPA is aware of other approaches for calculating 
``methane intensity'' currently in use. These include methodologies 
that allocate total methane emissions between the petroleum and natural 
gas value chains and/or use methane rather than natural gas as the 
throughput value. CAA section 136(f)(1) through (3) refers to reported 
facility emissions and does not discuss allocation of emissions between 
petroleum and natural gas. With the exception of production facilities 
that only produce oil, the statutory text clearly lists natural gas as 
the throughput value. Further, the proposed approach can be implemented 
with data currently reported under subpart W, while alternative methane 
intensity methodologies would require reporting of additional data and 
increase the burden on the oil and gas industry. For example, an 
approach that calculates intensity as methane emissions divided by the 
methane in natural gas throughput would require facilities to collect 
and report additional information of the methane content of natural 
gas. An approach that calculates methane intensity as the mass of 
methane emissions divided by the mass of natural gas would require 
facilities to collect and report detailed information on all of the 
constituents of natural gas throughput. Finally, an approach that 
allocates methane emissions between the petroleum and natural gas value 
chains based on energy content would require facilities to collect and 
report detailed data on the constituents and energy content of all 
hydrocarbon throughput. The EPA therefore believes that the proposed 
approaches not only follow a plain reading of CAA section 136(f) but 
are also the best and most reasonable approaches.
    The EPA invites comments on our proposed approach for calculating 
the waste emissions thresholds, particularly our proposed methodology 
and the underlying assumptions used to calculate the waste emissions 
threshold in metric tons of methane.
2. Facility Methane Emissions
    To determine the total methane emissions from a WEC applicable 
facility, the EPA proposes to use facility-level methane data as 
reported under subpart W. On August 1, 2023, the EPA proposed revisions 
to subpart W consistent with the authority and directives set forth in 
CAA section 136(h) as well as the EPA's authority under CAA section 114 
(88 FR 50282). Facility methane emissions (and any emissions associated 
with exemptions from the WEC) would be calculated using methods and 
data required by subpart W for the emissions year covered by the annual 
WEC filing. For example, for the first year of the WEC (2024 
emissions), WEC calculations would be based on the Subpart W 
requirements effective in 2024, and emissions year 2025 emissions and 
beyond would be based on Subpart W requirements effective in 2025 or 
any future revisions. The proposed approaches for calculating waste 
emissions thresholds and facility methane emissions align with the text 
of CAA section 136(f). CAA section 136(f)(1) through (3) states that 
the WEC is to be calculated based ``on the reported metric tons of 
methane emissions from such facility that exceed'' specified 
percentages of the ``natural gas sent to sale from such facility'' or 
``natural gas sent to sale from or through such facility'' (or for 
onshore and offshore petroleum facilities that do not send gas to sale, 
``ten metric tons of methane per million barrels of oil sent to sale 
from such facility''). The EPA proposes to interpret ``reported metric 
tons of methane emissions'' to mean all reported methane emissions from 
a facility, as reported under subpart W. This value is an input to 
equation B-6.
3. Facility WEC Calculation
    To calculate the amount by which a WEC applicable facility is below 
or exceeding the waste emissions threshold, the EPA proposes to use 
equation B-6 of 40 CFR 99.21, in which the facility waste emissions 
threshold, as determined in 40 CFR 99.20, is subtracted from facility 
total methane emissions. This calculation results in a value of metric 
tons of methane, the total facility applicable emissions, that is 
negative for facilities below the waste emissions threshold and 
positive for facilities exceeding the waste emissions threshold. The 
remainder of proposed 40 CFR 99.21 describes how to determine the WEC 
applicable emissions below or exceeding the waste emissions threshold 
considering any exemptions that may apply for WEC applicable facilities 
with total facility applicable emissions greater than 0 mt 
CH4 (see section II.D. of this preamble for more information 
on the exemptions). As discussed in section II.C.2.b. of this preamble, 
the EPA proposes that WEC applicable facilities receiving the 
regulatory compliance exemption would be exempted from the WEC, and 
therefore would have zero WEC applicable emissions. For facilities in 
the onshore petroleum and natural gas production and offshore petroleum 
and natural gas production industry segments with total facility 
applicable emissions greater than 0 mt CH4, any methane 
emissions associated with applicable exemptions would be subtracted to 
calculate WEC applicable emissions. For all other facilities, facility 
applicable emissions would equal WEC applicable emissions (unless the 
facility was receiving the regulatory compliance exemption).
    The EPA invites comments on the proposed approach for calculating 
WEC applicable emissions.
4. Netting
    The metric tons of methane emissions equal to, below, or exceeding 
the waste emissions threshold, or WEC applicable emissions, for each 
WEC applicable facility would be determined as specified in 40 CFR 
99.21. CAA section 136(f)(4) allows for the netting of emissions at 
facilities below the waste emissions thresholds with emissions at 
facilities exceeding the waste emissions thresholds for facilities 
under common ownership or control within and across all applicable 
industry segments identified in 136(d). The EPA proposes to implement 
netting using equation B-8 at 40 CFR 99.22. Equation B-8 would sum the 
WEC applicable emissions from all WEC applicable facilities under the

[[Page 5328]]

common ownership of control of a WEC obligated party to calculate net 
WEC emissions for that WEC obligated party. The EPA's proposed 
interpretation of common ownership and control and definition of WEC 
obligated party are discussed in section II.C. of this preamble.
5. Waste Emissions Charge Calculation
    CAA section 136(e) establishes annual $/metric ton charges for all 
methane emissions from WEC applicable facilities exceeding the waste 
emissions thresholds. The EPA proposes that a WEC obligated party's 
total annual WEC, or WEC obligation, would be calculated by multiplying 
its net WEC emissions, as determined by proposed Equation B-8, by the 
annual $/metric ton charge. WEC obligated parties with net WEC 
emissions less than or equal to zero would not have a WEC obligation. 
WEC obligated parties with net WEC emissions greater than zero would 
have a WEC obligation and be required to pay a waste emissions charge. 
WEC obligation calculations would be made for calendar years 2024, 
2025, 2026, and each year thereafter as per proposed 40 CFR 99.23.
6. Gathering and Boosting and Processing Facilities With Zero Reported 
Throughput
    The EPA is aware of a small number of gathering and boosting and 
natural gas processing facilities that emit methane and report under 
subpart W, but do not send gas to sale. As a result, these facilities 
would report zero natural gas volumes for the throughput metrics used 
in the proposed waste emissions threshold calculations. For the 
gathering and boosting industry segment, these may be facilities that 
receive natural gas but then reinject it underground or otherwise do 
not transport any natural gas. For the processing industry segment, 
these may be fractionation plants that only receive and process natural 
gas liquids (NGLs) and do not handle natural gas. Under the proposed 
approach, all reported methane emissions from facilities with no 
reported throughput would be considered to be exceeding the waste 
emissions threshold. The EPA notes that the proposed approach is based 
on a plain reading of the statutory text; because these facilities 
would have a calculated waste emissions threshold of zero, all reported 
methane would by default be exceeding the threshold. The EPA requests 
comment on the treatment of gathering and boosting and natural gas 
processing facilities that do not report any volumes for the proposed 
WEC throughput metrics. The EPA requests comment on the proposed 
approach that would consider all reported methane from these facilities 
to be above the waste emissions threshold. The EPA also requests 
comment on an alternative approach that would consider all reported 
methane emissions from these facilities to be below the waste emissions 
threshold.

C. Common Ownership or Control for Netting of Emissions

1. EPA Interpretation and Proposal To Implement ``Common Ownership or 
Control'' for the Purposes of Part 99
    CAA section 136(f)(4) allows WEC applicable facilities under 
``common ownership or control'' to net ``emissions by reducing the 
total obligation to account for facility emissions levels that are 
below the applicable thresholds within and across all applicable 
segments'' listed in section 136(d) and as defined in subpart W. The 
EPA interprets this to mean that for all eligible WEC applicable 
facilities under common ownership or control, the amount of metric tons 
of methane below the waste emissions thresholds (i.e., the difference 
between emissions equal to the waste emissions threshold and reported 
emissions) at facilities below the waste emissions threshold may be 
used to net against the amount of metric tons of methane emissions that 
exceed the waste emissions thresholds at facilities above the waste 
emissions threshold. For the purposes of establishing common ownership 
or control under CAA section 136(f)(4), the EPA proposes to define 
``WEC obligated party'' in 40 CFR 99.2. The EPA proposes that each 
subpart W facility would be associated with a single WEC obligated 
party (though each WEC obligated party may be associated with multiple 
subpart W facilities), which would be reported under the proposed 
requirements at 40 CFR 99.7. As discussed in section II.B.4. of this 
preamble and proposed in 40 CFR 99.22, all WEC applicable facilities 
associated with a common WEC obligated party would be able to net 
emissions for the purposes of calculating the WEC obligated party's net 
emissions and total WEC obligation.
    The EPA proposes that the WEC obligated party be the subpart W 
facility ``owner or operator'' as reported under 40 CFR 98.4(i)(3). The 
EPA proposes definitions for facility ``owner'' and ``operator'' that 
are applicable to the offshore petroleum and natural gas production, 
onshore natural gas processing, onshore natural gas transmission 
compression, underground natural gas storage, LNG import and export 
equipment, and LNG storage industry segments at 40 CFR 99.2. The 
onshore petroleum and natural gas production, onshore petroleum and 
natural gas gathering and boosting, and onshore natural gas 
transmission pipeline industry segments each have separate definitions 
for facility ``owner or operator'' proposed at 40 CFR 99.2. These 
proposed definitions are identical to the corresponding definitions in 
40 CFR part 98; the EPA proposes that the owner or operator associated 
with a subpart W facility as reported under 40 CFR 98.4(i)(3) 
(regarding the list of owners or operators of the facility for the 
certification of representation of the designated representative) would 
also be the WEC obligated party for that facility. The EPA believes 
that the proposed approach for using facility owner or operator for the 
purpose of defining common ownership or control aligns with a plain 
reading of the statutory text. CAA section 136(c) states that a charge 
on methane emissions that exceed the waste emissions threshold shall be 
imposed and collected ``from an owner or operator of an applicable 
facility.'' Further, in the context of required revisions to the 
subpart W methodologies used to calculate methane emissions, CAA 
section 136(h) states that those revisions must be made to ``allow 
owners and operators of applicable facilities to submit empirical 
emissions data, in a manner to be prescribed by the Administrator, to 
demonstrate the extent to which a charge under subsection (c) is 
owed.'' Thus, CAA section 136(c) requires the charge to be imposed and 
collected on a facility owner or operator, and CAA section 136(h) 
presumes that owners and operators are responsible for submitting 
empirical data. Furthermore, since the list of owners or operators for 
each facility is directly reported under 40 CFR 98.4(i)(3), an 
established program at the time that Congress drafted CAA section 136, 
the EPA proposes that under the best reading of the statutory text, the 
facility owner or operator would be used as the entity for establishing 
common ownership or control of subpart W facilities within and across 
all applicable subpart W industry segments.
    Although the EPA believes that the owner or operator approach is 
the most appropriate for netting under WEC, we seek comment on an 
alternative approach that would use the parent company of a facility's 
owner or operator for the WEC obligated party and determining common 
ownership or control of facilities. For each subpart W facility, the 
facility owner or operator

[[Page 5329]]

and parent company are reported under 40 CFR 98.4(i)(3) and 40 CFR 
98.3(c)(11), respectively. The parent company represents the highest-
level company based in the United States with an ownership interest in 
the facility. For parent company reporting, the percent ownership in 
the facility is also reported under 40 CFR 98.3(c)(11). Because a 
parent company has an ownership interest in a subpart W facility, 
multiple facilities may be said to be owned by the same parent company 
and might also be considered as being under common ownership or control 
of that parent company. So, one difference between using the owner or 
operator rather than a parent company for establishing common ownership 
or control is the number of facilities that may be brought under common 
ownership or control in each approach. For most facilities, the 
reported owner or operator is a subsidiary of the reported parent 
company. A single parent company may have multiple different owners or 
operators (i.e., subsidiaries) associated with facilities within and 
across subpart W industry segments. For example, an onshore petroleum 
and natural gas production facility and onshore natural gas processing 
facility owned by the same parent company may each have a different 
owner or operator. The number of ``common'' facilities is usually 
higher when the parent company is used, and lower when the owner or 
operator is used. The parent company approach would therefore provide a 
broader interpretation of common ownership or control relative to use 
of owner or operator. However, it is important to note that at the time 
CAA section 136 was enacted in 2022, the term ``common ownership or 
common control'' was a term used in the subpart W regulations. Under 
the subpart W regulations, the EPA has used the term ``common ownership 
or control'' to refer to the owner or operator, not to the parent 
company. Congress was likely aware of this definition when it enacted 
section 136. Therefore, the EPA is proposing to use facility owner or 
operator for the purpose of establishing common ownership or control 
based on a plain reading of CAA section 136(c), and believes that this 
is the better reading of the text in context with subpart W. However, 
the EPA requests comment on both the proposed approach using facility 
owner or operator and on an alternative approach using facility parent 
company for determining common ownership or control of WEC applicable 
facilities.
    In some cases, a WEC applicable facility may have multiple owners 
or operators reported under 40 CFR 98.4(i)(3). In these situations, the 
EPA proposes that the facility owners or operators would designate one 
of the owners or operators as the WEC obligated party for that 
facility, as proposed in 40 CFR 99.4. Under the proposed approach, the 
process for selection of the WEC obligated party at facilities with 
multiple owners or operators would be similar to the approach for 
selecting a designated representative under 40 CFR part 98. This 
process would require selection of a single WEC obligated party for the 
facility by an agreement binding on each of the owners or operators 
associated with the facility. The proposed approach for facilities with 
multiple owners allocates all facility-level methane emissions below or 
exceeding the waste emissions thresholds to a single WEC obligated 
party. We request comment on the proposed approach of allocating all 
methane emissions below or exceeding the waste emissions thresholds 
from a facility with multiple owners or operators to a single WEC 
obligated party. We request comment on other approaches that could be 
used to allocate emissions to owners or operators at facilities with 
multiple owners or operators. We request comment on the proposed 
approach of requiring the group of facility owners or operators to 
determine which owner or operator is the WEC obligated party, and 
alternative approaches for designating the WEC obligated party, at 
facilities with multiple owners or operators.
    The EPA also evaluated an approach that would allocate facility 
methane emissions below or exceeding the waste emissions thresholds at 
facilities with multiple owners to parent companies based on their 
reported percent ownership in the facility. Some subpart W facilities 
with multiple owners have parent companies with very small (i.e., less 
than one percent) equity shares. The minority owners may include 
individuals and small oil and gas companies with no operational control 
over the facility. Allocating methane emissions below or exceeding the 
waste emissions thresholds based on facility ownership would expose a 
larger number of individuals and small companies to potential WEC 
obligations. We note that allocating methane emissions from facilities 
with multiple owners to each owner based on facility ownership would 
only be possible using a parent company approach and not using the 
proposed owner or operator approach because GHGRP reporting does not 
currently include data on owner or operator facility equity share or 
include direct linkages between owners or operators and parent 
companies that could be used to assign facility ownership percentages 
to owners or operators. There may also be situations in which the 
facility owner or operator is a third-party operator with no ownership 
in the facility either directly or through their parent company.
    We request comment on an alternate approach that would allocate 
methane emissions to parent companies using percent ownership in the 
facility as well as other possible allocation methodologies for 
facilities with multiple parent companies. We request comment relevant 
to understanding other appropriate approaches for allocating emissions 
from a facility with multiple parent companies or owners or operators 
to a single WEC obligated party or multiple WEC obligated parties. For 
example, how are costs allocated at such facilities, and are they 
usually shared by parent companies (e.g., based on percent ownership in 
the facility), entirely borne by the facility operator, or does cost 
sharing vary based on facility-specific contractual agreements?
2. Facilities Eligible for the Netting of Emissions
    The EPA's proposed implementation of CAA section 136(f)(4) would 
define which types of applicable subpart W facilities are eligible to 
net emissions. We propose to establish netting eligibility criteria 
based on a facility's total reported subpart W GHG emissions, status in 
relation to the regulatory compliance exemption, and overall regulated 
status under the GHGRP. In our proposed approach to netting, we chose 
interpretations which were the most consistent with a plain reading of 
the CAA, as well as the most transparent and straightforward to 
implement. As described in more detail in the following sections, our 
approach assumes that if a facility's emissions are not subject to the 
WEC, either because the facility is not a WEC applicable facility, or 
because a WEC applicable facility receives the regulatory compliance 
exemption, that facility's emissions do not factor into the netting of 
emissions for a WEC obligated party. In other words, only WEC 
applicable facilities may net, and only WEC applicable emissions may be 
netted. As will be explained further in section II.C.2.a. of this 
preamble, we believe this interpretation is consistent with CAA section 
136(f)(4) ``the Administrator shall allow for the netting of emissions 
by reducing the total obligation to

[[Page 5330]]

account for facility emissions levels that are below the applicable 
thresholds within and across all applicable segments identified in 
subsection (d),'' since the reference to ``applicable thresholds'' and 
``applicable segments,'' which reflect other subsections under CAA 
section 136, implies that only WEC applicable emissions should be 
considered in the netting calculation. We note that for applicable 
facilities with unreasonable delay or plugged well exemptions, under 
the proposal, emissions associated with these exemptions would be 
removed from any emissions exceeding the waste emissions threshold 
prior to netting calculations.
a. Facilities Required To Report To GHGRP and That Have Subpart W 
Emissions Greater Than 25,000 Metric Tons of CO2e
    In accordance with CAA section 136(c) and the proposed definition 
of ``WEC applicable facility'' in 40 CFR 99.2, we are proposing that 
subpart W facilities that have subpart W emissions greater than 25,000 
mt CO2e are eligible for netting, with the exception of 
those that are receiving the regulatory compliance exemption (as 
discussed in section II.D.2. of this preamble). Facilities that report 
less than 25,000 mt CO2e under subpart W are not subject to 
the WEC, and the EPA proposes that such facilities would not be 
eligible for netting. These types of facilities are discussed in 
greater detail in section II.C.2.c. of this preamble. The EPA's 
proposed approach follows what the agency considers to be the best 
reading of the plain text of, and the relationship between CAA sections 
136(d), 136(c), and 136(f) (which includes subsections 136(f)(4) and 
136(f)(1)-(3)). The following sections will provide an overview of the 
relevant statutory text, and the corresponding basis for the EPA's 
belief that only WEC applicable facilities may net, and only WEC 
obligated emissions may be netted, under CAA section 136(f)(4).
    CAA section 136(d) introduces the nine industry segments within 
which all subpart W facilities must fall in order to be evaluated for 
WEC applicability. Importantly, facilities within these segments are 
``applicable facilities'', per CAA section 136(d), but they are not 
necessarily ``WEC applicable facilities'', subject to possible WEC 
obligation, unless they report over 25,000 mt CO2e per year 
under subpart W. CAA section 136(c) clarifies this point. Specifically, 
CAA section 136(c) requires the Administrator to impose and collect a 
charge on the owner or operator ``of an applicable facility that 
reports more than 25,000 metric tons of carbon dioxide equivalent of 
greenhouse gases emitted per year pursuant to subpart W''. Thus, 
building upon the CAA section 136(d) definition, CAA section 136(c) 
establishes that only facilities which both fall within one or more of 
the nine CAA section 136(d) industry segments and report more than 
25,000 mt CO2e under subpart W are subject to the WEC 
program. For clarity, in this rulemaking the EPA refers to these 
facilities as ``WEC applicable facilities''.
    CAA section 136(f), which is entitled ``Waste Emissions 
Threshold'', includes a series of subsections under this heading. 
Subsections 136(f)(1)-(3) illustrate the meaning of ``waste emissions 
threshold'' in this context, and explain that these are actually a 
series of thresholds which determine when and how to impose a charge on 
methane emissions from WEC applicable facilities, depending on which 
industry segment or segments they fall under. Specifically, the nine 
CAA section 136(d) industry segments are categorized into four groups, 
and a waste emissions threshold is applied to each of the four. CAA 
section 136(f)(1) covers offshore and onshore petroleum and natural gas 
production (industry segments (1) and (2) under CAA section 136(d)), 
and further divides this category depending on whether or not natural 
gas is sent to sale: ``With respect to imposing and collecting the 
charge under subsection (c) for an applicable facility in an industry 
segment listed in paragraph (1) or (2) of subsection (d), the 
Administrator shall impose and collect the charge on the reported 
metric tons of methane emissions from such facility that exceed (A) 
0.20 percent of the natural gas sent to sale from such facility; or (B) 
10 metric tons of methane per million barrels of oil sent to sale from 
such facility, if such facility sent no natural gas to sale.'' \22\
---------------------------------------------------------------------------

    \22\ 42 U.S.C. at 7436(f)(1).
---------------------------------------------------------------------------

    CAA sections 136(f)(2) and (3) follow the same model: section 
136(f)(2) establishes thresholds for nonproduction petroleum and 
natural gas systems (industry segments (3), (6), (7), and (8) under 
section 136(d)),\23\ and imposes a charge on ``the reported metric tons 
of methane emissions that exceed 0.05 percent of the natural gas sent 
to sale from or through such facility;'' \24\ and section 136(f)(3) 
establishes thresholds for natural gas transmission (industry segments 
(4), (5), and (9)) \25\ and imposes a charge on ``the reported metric 
tons of methane emissions that exceed 0.11 percent of the natural gas 
sent to sale from or through such facility.'' \26\ But each industry-
specific threshold is introduced in the same way: ``With respect to 
imposing and collecting the charge under subsection (c) for an 
applicable facility in an industry segment listed in paragraph (x) of 
subsection (d), [charges shall be imposed as follows]''. Following this 
plain text, it is clear that the CAA section 136(f) waste emission 
thresholds apply only to WEC applicable facilities-that is, facilities 
within one or more of the nine WEC industry segments listed in CAA 
section 136(d) which emit more than 25,000 mt per year CO2e 
under subpart W, and thus may be subject to charge under CAA section 
136(c).
---------------------------------------------------------------------------

    \23\ Specifically: (3) onshore natural gas processing; (6) 
liquefied natural gas storage; (7) liquefied natural gas import and 
export equipment; and (8) onshore petroleum and natural gas 
gathering and boosting.
    \24\ Id. at section 7436(f)(2).
    \25\ Specifically, (4) onshore natural gas transmission 
compression; (5) underground natural gas storage; and (9) onshore 
natural gas transmission.
    \26\ Id. at section 7436(f)(3).
---------------------------------------------------------------------------

    Finally, in the netting provision itself, CAA section 136(f)(4), 
states that ``in calculating the total emissions charge obligation for 
facilities under common ownership or control, the Administrator shall 
allow for the netting of emissions by reducing the total obligation to 
account for facility emissions levels that are below the applicable 
thresholds within and across all applicable segments identified in 
subsection (d)''. As noted above, the EPA is proposing that this 
netting provision applies to WEC applicable facilities and WEC 
applicable emissions only, for three compelling reasons.
    First, the EPA believes that per the best reading of the statute, 
the term ``applicable thresholds'' refers to the waste emission 
thresholds outlined in CAA section 136(f)(1)-(3). This is important 
because, as noted above, the waste emissions thresholds apply only to 
WEC applicable facilities--they determine whether, and how, a charge 
shall be imposed on methane emissions from a facility which has already 
been triggered into the WEC program by virtue of its 25,000 mt per year 
CO2e in subpart W. The thresholds do not apply to facilities 
which emit fewer than 25,000 mt per year of CO2e under 
subpart W, because under CAA section 136(c), no charge may be imposed 
or collected on such facilities. Facilities which emit less than 25,000 
mt per year of CO2e under subpart W may emit any amount of 
methane, but these methane emissions are not WEC applicable emissions: 
they cannot be evaluated according to the waste emissions

[[Page 5331]]

thresholds, and they cannot be considered to fall either above or below 
these thresholds. Thus, in ``account[ing] for facility emissions levels 
that are below the applicable thresholds'', the EPA understands that it 
must account for WEC applicable emissions from WEC applicable 
facilities which fall below the waste emissions thresholds, and produce 
a negative value under Equation B-6 (see above at section II.B.3.).
    As previously stated, EPA's conclusion that the term ``applicable 
thresholds'' in CAA section 136(f)(4) refers to the waste emissions 
thresholds outlined in CAA section 136(f)(1)-(3) is supported by both 
the text and structure of the statute. First, the structure of the 
statute strongly supports the presumption that CAA section 136(f)(4) 
refers to netting based on a facility's relationship to the waste 
emissions thresholds because CAA section 136(f)(4) appears as part of 
CAA section 136(f), under the ``waste emissions threshold'' heading, 
and immediately following CAA section 136(f)(1)-(3)'s establishment of 
the specific waste emissions thresholds for each industry segment. It 
follows that CAA section 136(f)(4)'s reference to ``applicable 
thresholds'' refers to these industry segment-specific requirements, 
and accordingly ``applicable segments'' refers to the industry segments 
identified in CAA section 136(f)(1)-(3).
    A close reading of the text also strongly supports our presumption 
regarding the waste emissions thresholds, because CAA section 136(f)(4) 
refers to facility emissions levels that are ``below the applicable 
thresholds,'' plural. The use of the plural, and the use of the term 
``applicable,'' both indicate that Congress was referring here to the 
multiple waste emissions thresholds introduced in CAA sections 
136(f)(1) through (3), which specifically and separately apply to WEC 
applicable facilities within various subsets of industry segments, 
defined in CAA section 136(d). Again, these separate thresholds only 
apply to WEC applicable facilities, which emit over 25,000 tons per 
year of CO2e per year.
    In addition to the ``applicable thresholds'' question, the EPA 
believes that Congress's use of the term ``applicable segments'' in 
stating that EPA may ``redu[ce] the total obligation to account for 
facility emissions levels that are below the applicable thresholds 
within and across all applicable segments identified in subsection 
(d),'' is significant here. While CAA section 136(d) introduces the 
nine relevant ``industry segments'' within which all WEC applicable 
facilities must fall, CAA section 136(f)(4) classes these segments into 
four groups, and is the only provision to use the term ``applicable 
segments''. As noted above, CAA section 136(f) establishes a set of 
requirements determining when and how to impose a charge on those 
facilities triggered into the program, depending on their industry 
segment and the amount of methane they emit. It follows that CAA 
section 136(f)(4)'s reference to ``applicable thresholds'' refers to 
these four group-specific thresholds, and ``applicable segments'' 
refers to the nine segments within the four segment groups. In other 
words, each group of segments constitutes the ``applicable'' segments 
to their corresponding applicable threshold. This is important, again 
because the four groups laid out under CAA section 136(f) include only 
WEC applicable facilities.
    Finally, Congress's statement that netting shall be employed ``in 
calculating the total emissions charge obligation for facilities under 
common ownership or control'', further indicates that only WEC 
applicable facilities may be netted. Logic indicates that only WEC 
applicable facilities, with WEC applicable emissions, would be relevant 
to a determination of total emissions charge obligation. As regards the 
WEC program, WEC obligated parties are concerned with methane emissions 
for the WEC applicable facilities for which they are responsible--not 
various other subpart W facilities for which a WEC charge can never be 
imposed. Accordingly, the EPA believes that under the best reading of 
this provision WEC obligated parties may net WEC applicable methane 
emissions between facilities in different segments, as long as all 
facilities are WEC applicable facilities.
b. Facilities With Subpart W Emissions Greater Than 25,000 Metric Tons 
of CO2e That Are Receiving the Regulatory Compliance 
Exemption
    The EPA proposes that during such time that a facility receives the 
regulatory compliance exemption, that facility would have zero WEC 
applicable emissions and thus would not be able to participate in the 
netting of methane emissions across facilities under common ownership 
or control of a WEC obligated party. The EPA's proposed approach is 
based on a plain reading of the statutory text, and follows the same 
reasoning outlined in section II.C.2.a. of this preamble, which 
explains that under the best reading of the text, only WEC applicable 
facilities may net.. This section will further expand upon EPA 
reasoning that only WEC applicable emissions may be netted, and clarify 
this point for purposes of the regulatory compliance exemption.
    CAA section 136(f)(6)(A) states that ``[c]harges shall not be 
imposed pursuant to subsection (c) on an applicable facility that is 
subject to and in compliance with methane emissions requirements 
pursuant to subsections (b) and (d) of section 111'' if specific 
criteria are met (these criteria are discussed in section II.D.2. of 
this preamble). The EPA's interpretation of the regulatory compliance 
exemption is that, for a WEC applicable facility meeting the exemption 
criteria, the entire facility is exempted, and therefore the facility 
does not generate WEC-applicable emissions. In order to net, facilities 
must be WEC applicable facilities (they must emit over 25,000 
CO2e per year under subpart W) and they must also generate 
WEC applicable emissions (methane emissions below or above the WEC 
emissions thresholds that are subject to charge.) Again, this follows 
from the text. Section 136(f)(4) applies ``in calculating the total 
emissions charge obligation'' only. Emissions which are subject to an 
exemption are by definition not subject to charge. WEC applicable 
emissions are only those emissions subject to charge under section 
136(c). Because, under the proposed approach WEC applicable facilities 
with the regulatory compliance exemption would have zero WEC applicable 
emissions, these facilities would by default not be able to participate 
in netting (i.e., they would have no emissions to net). The proposed 
approach of facilities with the regulatory compliance exemption having 
zero WEC applicable emissions allows for the practical implementation 
of the exemption within the broader framework of the proposed WEC 
calculations. Assigning exempted facilities zero WEC applicable 
emissions ensures that charges shall not be imposed on these facilities 
without interfering with netting calculations or removing facility-
specific reporting elements necessary for WEC implementation. Such 
facilities would continue to be included in WEC filings reported under 
part 99 as long as they remain WEC applicable facilities. Further, if 
such facilities fall out of compliance such that the regulatory 
compliance exemption no longer applies and they again generate WEC 
applicable emissions, such facilities would again be included in 
netting.
    The EPA notes that under the proposed approach, facilities with 
emissions below the waste emissions

[[Page 5332]]

threshold would not receive the regulatory compliance exemption (see 
discussion in section II.D.2.f. of this preamble), and thus these 
facilities would always have WEC applicable emissions and would be able 
to participate in netting across facilities under common ownership or 
control.
    The EPA requests comment on the proposed approach in which WEC 
applicable facilities receiving the regulatory compliance exemption 
would have zero WEC applicable emissions. The EPA requests comment on 
other options for WEC applicable facilities receiving the regulatory 
compliance exemption and their treatment in the context of netting.
c. Exclusion of Facilities Reporting 25,000 or Fewer Metric Tons of 
CO2e to Subpart W of Part 98
    Per CAA section 136(c), the WEC shall only be imposed on owners or 
operators of applicable facilities that report more than 25,000 mt 
CO2e under subpart W. A large number of facilities that 
report under the GHGRP have subpart W emissions below 25,000 mt 
CO2e. A part 98 subpart W facility is generally allowed to 
cease reporting or ``offramp'' due to meeting either the 15,000 mt 
CO2e level or the 25,000 mt CO2e level for the 
number of years specified in 40 CFR 98.2(i) based on the 
CO2e reported, as calculated in accordance with 40 CFR 
98.3(c)(4)(i) (i.e., the annual emissions report value as specified in 
that provision). Some facilities have dropped below 25,000 mt 
CO2e in total reported emissions to part 98 and are 
continuing to report while on the reporting offramp. Other facilities 
report emissions under multiple subparts (e.g., subpart W and subpart 
C) and have total emissions equal to or greater than 25,000 mt 
CO2e across both subparts, but subpart W emissions below 
25,000 mt CO2e. The latter category includes processing 
plants, transmission compressor stations, underground storage 
facilities, LNG storage facilities, and LNG import and export 
facilities that report their combustion emissions under subpart C. Many 
of these facilities have total GHGRP emissions exceeding 25,000 mt 
CO2e, but subpart W emissions that alone fall below this 
threshold.
    We are proposing that subpart W facilities with subpart W emissions 
equal to or below 25,000 mt CO2e are not WEC applicable 
facilities and are therefore excluded from netting. This proposed 
approach aligns with a plain reading of the requirement in CAA section 
136(c) that only applicable facilities with subpart W emissions 
exceeding 25,000 mt CO2e are subject to the WEC--facilities 
below this threshold are not subject to the WEC and therefore do not 
generate WEC applicable emissions and are not able to net emissions.
d. Exclusion of Facilities Not Required To Report to the GHGRP
    Per CAA section 136(c) and (d), CAA section 136(f)(4), and the 
proposed definition of ``WEC Applicable Facility'' in 40 CFR 99.2, 
which reflects the statutory text at CAA section 136(d), we are 
proposing that facilities that are not required to report to the GHGRP, 
and thus are not WEC applicable facilities, would not be eligible for 
netting. Again following the reasoning outlined in section II.C.2.a. of 
this preamble, the EPA's proposed approach is based on a plain reading 
of CAA section 136(f)(4), which states that netting is allowed within 
and across the nine subpart W industry segments identified in CAA 
section 136(d); section 136(d), which states that ``applicable 
facility(ies)'' are facilities within industry segments ``as defined in 
subpart W''; and section 136(c), which states that the WEC is only 
applicable to subpart W facilities that report more than 25,000 
CO2e per year. Following the plain text, only facilities 
subject to subpart W may be evaluated as possible WEC applicable 
facilities, and only WEC applicable facilities (subpart W facilities 
emitting over 25,000 CO2e) can have WEC applicable emissions 
that may be subject to charge. As explained in section II.C.2.a. of 
this preamble, only WEC applicable facilities may net, and only WEC 
applicable emissions may be netted. Further, CAA section 136(c) states 
that the WEC is only applicable to certain facilities that report under 
subpart W of the GHGRP.

D. Exemptions to the Waste Emissions Charge

1. Exemption for Emissions From Eligible Delays in Environmental 
Permitting Under CAA Section 136(f)(5)
    CAA section 136(f)(5) establishes an exemption for emissions 
resulting from delay in environmental permitting by stating, ``Charges 
shall not be imposed pursuant to paragraph (1) on emissions that exceed 
the waste emissions threshold specified in such paragraph if such 
emissions are caused by unreasonable delay, as determined by the 
Administrator, in environmental permitting of gathering or transmission 
infrastructure necessary for offtake of increased volume as a result of 
methane emissions mitigation implementation.''
    This provision would exempt from the charge certain emissions 
occurring at facilities in the onshore and offshore production 
segments. Paragraph (1) referenced in the exemption refers to CAA 
section 136(f)(1), which establishes the waste emissions threshold for 
applicable facilities in the production sector, as discussed in section 
II.B. of this preamble. The exemption is limited to emissions occurring 
as a result of certain delays in permitting of gathering or 
transmission infrastructure necessary for offtake of increased volume 
as a result of methane emissions mitigation implementation. 
Infrastructure necessary for offtake would include gathering and 
transmission pipelines and compressor stations. Increased volume as a 
result of methane emissions mitigation implementation would include 
increased natural gas amounts available for transport that would have 
otherwise been emitted.
a. Emissions Eligible for the Permitting Delay Exemption
    Given the complexity of defining and determining ``unreasonable 
delay'' related to environmental permitting, the EPA is proposing a 
simplified approach of establishing a set of four criteria for applying 
the unreasonable delay exemption established by CAA section 136(f)(5). 
These criteria would only apply in the context of determining eligible 
emission exemptions for the implementation of CAA 136(f)(5) and this 
proposed rulemaking; they are not intended to speak to the 
reasonableness of a permitting delay in any other context. The EPA 
understands that the issue of what constitutes an unreasonable delay is 
multi-faceted and may be quite different under different factual 
circumstances. At the same time, the EPA believes it is important in 
the context of this program to propose a definition that is both 
consistent with the statutory charge and administrable within the 
capabilities of the EPA. With those caveats in mind, the EPA proposes 
the following four criteria for implementing this exemption: (1) the 
facility must have emissions that exceed the waste emissions threshold; 
(2) neither the entity seeking the exemption, nor the entity 
responsible for seeking the permit, may have contributed to the delay; 
(3) the exempted emissions must be those (and only those) resulting 
from the flaring of gas that would have been mitigated without the 
permit delay, and the flaring that occurs must be in compliance with 
all applicable local, state, and Federal regulations regarding flaring 
emissions; and (4) a set period of months must have passed from the 
time a submitted permit application was

[[Page 5333]]

determined to be complete by the applicable permitting authority.
    The EPA believes this approach meets the Congressional intent of 
this exemption while creating a program that can be implemented 
annually allowing for collection of WEC in a timely manner. The 
proposed approach is intended to reduce burden on the companies and 
government compared with an approach that would not specify a timeframe 
or other criteria but would rely on decisions made on a case-by-case 
basis to determine whether the timing and other circumstances of an 
individual permitting action constitutes an unreasonable delay. We 
note, however, that these criteria outlined above, including the 
timeframe, are proposed for the purpose of defining the emissions 
eligible for an exemption for the purposes of the implementation of CAA 
136(f)(5) and this proposed rulemaking only and are not applicable for 
defining an unreasonable delay outside of this context. The criteria 
introduced in this section do not apply to the determination of 
unreasonable delay for purposes of the National Environmental Policy 
Act (NEPA), the Administrative Procedure Act (APA), or any other law 
involved in permitting processes or any other agency actions. In 
particular, the timeline criterion should not be considered applicable 
or informative to the determination of unreasonable delay in any 
context other than determining emission exemptions for the 
implementation of CAA 136(f)(5) and this proposed rulemaking.
    The first criterion, that the facility must have emissions that 
exceed the waste emissions threshold, is based on CAA 136(f)(5), which 
states that ``charges shall not be imposed pursuant to paragraph (1) on 
emissions that exceed the waste emissions threshold specified in such 
paragraph if such emissions are caused by unreasonable delay.'' A 
straightforward reading of this language limits the exemption to 
emissions exceeding the waste emissions threshold. In addition, since 
charges would not be imposed on emissions below the threshold, an 
exemption is unnecessary in cases where facility emissions are below 
the threshold. The EPA proposes that emissions from facilities that are 
below the waste emissions threshold would not be exempted. The EPA 
proposes that for facilities that exceed the waste emissions threshold, 
emissions eligible for the permitting delay exemption would be 
subtracted from the facility emissions that exceed the waste emissions 
threshold. The exempted emissions would not be used to reduce emissions 
totals below the threshold (i.e., the lowest possible WEC applicable 
emissions for a facility with the exemption would be zero).
    The second criterion relates to responsiveness on the part of the 
production sector WEC applicable facility reporting emissions caused by 
a delay in gathering or transmission infrastructure and the gathering 
or transmission infrastructure permit applicant: neither the entity 
potentially eligible for the exemption (i.e., a WEC applicable facility 
in the onshore or offshore production sector) nor the entity seeking 
the environmental permit (e.g., an entity seeking a permit for 
gathering or transmission infrastructure) has contributed to the delay 
in permitting.
    The EPA is proposing that contributions to the delay by either the 
production entity potentially eligible for the exemption or the entity 
seeking the environmental permit would be determined based upon the 
timeliness of response to requests for additional information or 
modification of the permit application. Delays in response exceeding 
the response time requested by the permitting agency, or requested by 
the relevant production or gathering or transmission infrastructure 
entity seeking the permit, or responses that exceed 30 days from the 
request if no specific response time is requested, would be considered 
to contribute to the delay in processing the permit application. Note 
that this proposed determination of what would constitute a delay 
eligible for the exemption in environmental permitting would be 
specific solely to implementation of CAA section 136(f)(5) and this 
proposed rulemaking for part 99, and would not necessarily be 
applicable to any other section of the CAA, or any permitting program 
administered by the EPA or by a state or local permitting authority.
    The third criterion is that the exempted emissions must be those 
resulting from the flaring of gas that would have been mitigated 
without the permit delay--and that exempted emissions must be in 
compliance with all applicable local, state, and Federal regulations 
regarding flaring emissions. The EPA believes that this approach 
reasonably follows from the text of section 136(f)(5), which exempts 
emissions caused by unreasonable delay in the permitting of ``gathering 
or transmission infrastructure necessary for offtake of increased 
volume as a result of methane emissions mitigation implementation.'' 
\27\ Following this statutory directive, the EPA is proposing that 
exempted emissions are flaring emissions which (1) would otherwise be 
captured in accordance with applicable regulations but (2) are not 
captured due to a delay in the permitting necessary for offtake. It is 
anticipated that operations seeking the exemption could include oil 
production sites planning to send gas to sale, rather than flaring the 
emissions, or facilities that produce natural gas, condensate or 
natural gas liquids and that expand operations and are flaring gas 
because a pipeline is not yet available. Only flaring emissions caused 
by the unreasonable delay in permitting, and occurring in compliance 
with all applicable regulations, would be exempt. Other emissions 
occurring at the wellsite would not be exempt because they are not 
associated with the delay or because they do not occur in compliance 
with applicable regulations. For example, fugitive emissions from leaks 
would occur with or without the delayed infrastructure, and venting 
emissions is widely restricted due to Federal, state, or local 
regulations on venting.
---------------------------------------------------------------------------

    \27\ 42 U.S.C. 7436(f)(5) (emphasis added).
---------------------------------------------------------------------------

    Flaring emissions that occur as a result of flaring that is not in 
compliance with applicable regulations are ineligible for the 
exemption. This approach accords with the text of section 136(f)(5), 
which states that the exemption is for emissions occurring as a result 
of unreasonable delay in permitting required for the build out of 
infrastructure ``necessary for offtake of increased volume as a result 
of methane emissions mitigation.'' \28\ Regulations limiting flaring 
and venting will result in an increased volume of gas that must be 
captured and transmitted, compared with a circumstance without methane 
emissions mitigation implementation, in which gas is flared or vented 
on site. Thus, the EPA understands that this provision is designed to 
exempt flaring done in compliance with regulations, where sources are 
prepared to capture gas but cannot yet do so due to lack of offtake 
infrastructure. However, a delay in permitting does not allow exemption 
from other applicable local, state, and Federal regulations regarding 
flaring. Thus, the flaring emissions exempt under 136(f)(5) cannot 
exceed flaring emissions allowable under other applicable local, state, 
and Federal regulations.
---------------------------------------------------------------------------

    \28\ 42 U.S.C. 7436(f)(5)
---------------------------------------------------------------------------

    The fourth criterion is that an eligible ``unreasonable delay'' 
would be a delay that exceeds a set period of months specified in the 
final rule. The EPA's current assessment is that this time period would 
likely fall somewhere between 30 and 42 months from the date that a 
submitted permit application

[[Page 5334]]

was determined to be complete by the relevant permitting authority. 
This time period is not tied to the timing of the WEC; a facility that 
meets all four criteria would be eligible for the exemption in the 
first year of the WEC if the time period requirement has been met. The 
relevant permitting authority could be the United States Federal Energy 
Regulatory Commission (FERC), or other federal, state or local agencies 
that issue environmental permits. The environmental permitting process 
can require multiple steps including, but not limited to: the entity 
preparing and submitting a permit application; the entity responding to 
comments with supporting information; the regulatory agency preparing a 
draft permit; public comment; and preparation and issuance of the final 
permit. Target dates for permit actions can vary by regulatory agency 
and depend, for example, on whether the relevant permit is for a new or 
existing source, or whether the action is a major or minor 
modification. The EPA is proposing to set a timeframe for unreasonable 
delay that is not specific to particular permitting actions or agency 
timelines.
    The EPA is proposing to set a timeline somewhere in the range of 30 
to 42 months, with the default to be specified in the final rule after 
consideration of comments received. This preliminary range is based on 
the EPA's current understanding of timelines for oil and gas permitting 
across Federal agencies. In particular, the preliminary range is 
informed by the EPA's review of data made available through the Federal 
Permitting Improvement Steering Council (FPISC) through Title 41 of the 
Fixing America's Surface Transportation Act (FAST-41). The 
``Recommended Performance Schedules for 2020'' released by FPISC 
contains data for the Federal review and permitting of 18 pipeline 
projects under the FAST-41 program.\29\ For these projects, the mean 
time from receipt by FERC of a complete application to the issuance of 
a certificate of public convenience and necessity for interstate 
natural gas pipelines was 23 months, with three of the 18 projects (17 
percent) exceeding 30 months. Criteria for inclusion in the FAST-41 
program include projects that are considered likely to require 
investment exceeding $200,000,000 and that do not qualify for 
abbreviated review under applicable law; or projects of a size and 
complexity that the FPISC determines are likely to benefit from 
inclusion.\30\ On this basis, the EPA believes the FAST-41 dataset may 
be a conservative population (i.e., require more complex environmental 
review and permitting) when compared to the total of all gathering or 
transmission infrastructure projects.
---------------------------------------------------------------------------

    \29\ Federal Permitting Improvement Steering Council, ``2020 
Recommended Performance Schedules.'' Federal Infrastructure 
Permitting Dashboard. April 6, 2020. https://www.permits.performance.gov/fpisc-content/recommended-performance-schedules. Accessed August 28, 2023.
    \30\ Federal Permitting Improvement Steering Council, ``FAST-41 
Fact Sheet.'' Federal Infrastructure Permitting Dashboard. September 
13, 2022. https://www.permits.performance.gov/documentation/fast-41-fact-sheet. Accessed August 28, 2023.
---------------------------------------------------------------------------

    The proposed range of 30 to 42 months also takes into account the 
2023 Fiscal Responsibility Act, which set a limit under the National 
Environmental Policy Act of 1 year for completion of an Environmental 
Assessment and 2 years for completion of an Environmental Impact 
Statement unless extended by the lead agency in consultation with the 
applicant or project sponsor. However, the amount of time necessary to 
complete an Environmental Assessment or Environmental Impact Statement 
will vary depending on the specific agency action at issue, and this 
proposed timeline is not intended to reflect a determination of the 
reasonable length of a time necessary to complete such analysis in any 
specific instance. For projects requiring approval or permitting from a 
federal agency, completion of an Environmental Assessment or 
Environmental Impact Statement must occur prior to the agency taking a 
final agency action. Additional steps in the process that must be 
completed following completion of review under NEPA may add several 
months to the overall timeframe (e.g., convening of FERC to approve or 
deny a certificate of public convenience and necessity).
    We note that all four criteria must have been met for the EPA to 
determine that for the purpose of this exemption, emissions were caused 
by an unreasonable delay. No single factor, including timing, would be 
determinative as to whether a delay unreasonable in the context of this 
exemption. We are not assessing whether a delay of any particular 
period of months alone (i.e., in the absence of the other three 
criteria) should be considered unreasonable in the context of this 
exemption, and we are not assessing the reasonableness of a particular 
timeframe or collection of conditions outside of the context of this 
exemption specific to CAA section 136. An assessment of reasonableness 
in any other context depends on the circumstances specific to that 
context, which can vary considerably and there is no straightforward 
way to determine whether a delay is reasonable or unreasonable that 
applies to all contexts. We note that using the approach of requiring 
four criteria to be met may not fully capture case-by-case 
circumstances and therefore may not always produce the same 
determination as a more holistic evaluation would. We have proposed 
this approach of using four criteria, including one specifying a set 
timeframe, for the purposes of this exemption only to simplify this 
process, and for clarity and administrability; we understand that 
longer permitting timeframes are often not unreasonable in other 
contexts.
    As an alternative to specifying that an ``unreasonable delay'' 
requires a set period of months to have elapsed since a permit 
application is deemed complete (in addition to the other three 
criteria), the EPA considered adopting a case-by-case process for 
determining whether an unreasonable delay in permitting has occurred. 
Under such an approach, the exemption for unreasonable delay could only 
be utilized by a facility that has obtained a facility-specific finding 
of unreasonable delay from the EPA. The EPA would evaluate 
documentation provided by a WEC obligated party to determine if there 
was an unreasonable delay. A WEC obligated party would not exclude 
emissions it claimed are associated with the unreasonable delay 
exemption until such time as it obtained an unreasonable delay finding 
from the EPA. In other words, emissions associated with a claim of 
unreasonable delay for which there is not an unreasonable delay 
determination by the EPA could not be subtracted from the emissions 
totals in the initial WEC filing. If the EPA subsequently were to make 
such a finding, the EPA would authorize a refund in accordance with its 
determination. Documentation could include information such as that 
currently proposed to be reported, such as information on mitigation 
activities, permitting timing, and regulations relevant to flaring, and 
information currently proposed as recordkeeping requirements, such as 
detailed records on responsiveness, in addition to other documentation 
specific to the relevant gathering or transmission infrastructure 
environmental permit, such as on the expected timing for the specific 
environmental permit(s) sought and the type of information that would 
be needed to support the claim that the permit(s) is delayed beyond 
what could be considered a reasonable timeframe. A case-by-case 
approach for reviewing and

[[Page 5335]]

approving the unreasonable delay exemption would help ensure the 
validity of individual claims, and ensure that all applicable waste 
emissions for each facility are subject to charge, as directed by 
Congress. However, the EPA decided not to propose such an approach due 
to the time and resource burden that would be required to administer 
such a process, for both covered entities and for the EPA. We expect 
that many types of permitting situations can arise, with many 
permutations. If industry were required to demonstrate unreasonable 
delay on a case-by-case basis, the EPA anticipates this review process 
would result in uncertainty for industry and could lead to a 
significant backlog, thus making the annual calculation of the WEC 
unduly burdensome. Therefore, in the interest of simplicity and making 
the exemption available in an efficient manner and without significant 
additional burden, the EPA proposes to rely on this threshold of a set 
period of months, in addition to the three other criteria, which can be 
more easily applied without detailed investigation. The EPA notes that 
in its verification process under the proposed approach it would review 
the submitted documentation to confirm that requirements are met for 
each facility reporting an unreasonable delay, and facilities 
determined to have not met the requirements would be required to submit 
any additional owed WEC obligation and relevant penalties.
    Section II.D.1.c. below details the reporting requirements for this 
exemption which provide information necessary for verification of the 
exemption eligibility and exempted emission quantities.
    We seek comment on these four criteria, each required to be met to 
determine emissions eligible for the unreasonable delay exemption. We 
seek comment on the use of responsiveness to requests regarding 
permitting by the permit applicant or the production segment facility 
experiencing delayed mitigation as a criterion. We seek comment on the 
use of 30 days to assess responsiveness where a specific timeframe for 
response is not provided. We seek comment on the criterion that 
exempted emissions are those resulting from flaring of gas that would 
have been mitigated without the permit delay, and that only flaring 
emissions that are in compliance with applicable regulations are 
eligible. We seek comment on the appropriate timeframe to be used as 
part of the four-factor test proposed today--specifically, what would 
be the best period of time (even if it is below or above the 30-42-
month range EPA is leaning towards now) to use as a trigger for 
assessing unreasonable delay for the purposes of CAA section 136(f). We 
seek comment on the proposed use of one timeframe for eligibility 
versus an approach that might use different time frames for different 
types of permits. We seek comment on whether specific types of delays 
should be eligible or ineligible, which could be included as additional 
criteria or used in place of all or some of the proposed criteria. For 
example, we seek comment on whether we should establish that delays due 
to litigation regarding pipeline development are ineligible. We also 
seek comment on an alternative case-specific approach in which each 
facility with exempt emissions from unreasonable delay would provide 
additional facility- and permit-specific information, and in which the 
exemption would not be granted unless approved by the EPA. Finally, we 
seek comment on whether EPA should include additional criteria when 
defining the unreasonable delay exemption. For example, we seek comment 
on whether, in addition to the four criteria, we should add a criterion 
that entities show the flaring is necessary (i.e., other options for 
beneficially use or reinject of gas were infeasible).
b. Calculation of Emissions Resulting From an Unreasonable Delay
    Through the provisions proposed at 40 CFR 99.32, the EPA is 
proposing that exempted emissions are flaring emissions caused by the 
delay. We are proposing that exempted flaring emissions are the methane 
emissions (or a subset of the methane emissions) from flaring reported 
under subpart W.
    To calculate the exempted emissions quantity, the entity must 
determine the time period associated with the emissions that occurred 
as a result of the delay within the filing year. The EPA is proposing 
that the delay begins when emissions would have been avoided through 
the operation of the gathering or transmission infrastructure, not when 
construction would begin, as in many cases the infrastructure would not 
be immediately in place and operational at the time of permitting 
approval. For example, a permit to construct might be needed before 
construction begins, and construction could take months or more before 
the infrastructure would be in place.
    Where the exempted emissions cover the entire reporting year, the 
exempted flaring emissions would be the total reported to part 98 for 
flare stacks, associated gas flaring, and the portion of offshore 
methane emissions attributable to flaring. Where exempted emissions 
occur in only a fraction of a reporting year, the facility is to use 
data on flaring emissions over that time frame if available, and if 
unavailable, the facility is to adjust part 98 flaring emissions using 
the fraction of the year that the exemption is available. Where flared 
emissions impacted by permitting delay only account for a portion of 
the total flared emissions, the facility is to adjust their part 98 
reported flaring emissions using company records and/or engineering 
calculations.
    We seek comment on the provisions proposed, including the use of 
reported flaring emissions to determine exempted emissions, the use of 
part 98 data, and the approaches for quantifying emissions for 
fractions of the reporting year.
c. Reporting and Recordkeeping Requirements for the Exemption for 
Emissions Resulting From a Permit Delay
    Through the provisions proposed at 40 CFR 99.31, the EPA is 
proposing that the WEC obligated party receiving the exemption would 
provide information on each well pad or offshore platform impacted by 
the delay. This includes the type of permit, permitting authority, and 
the date that the permit application was complete. The WEC obligated 
party must report the planned timing of the commencement of the offtake 
of gas had the permit not been delayed. This includes a listing of the 
methane emissions mitigation activities that are impacted by the delay 
and the flaring emissions associated with natural gas that would have 
been directed to gathering or transmission infrastructure as a result 
of the methane emissions mitigation activities. This also includes 
information on all applicable local, state, and Federal regulations 
regarding flaring emissions and the facility's compliance with each. 
The WEC obligated party must report the time period associated with the 
emissions that occurred as a result of the delay within the filing 
year. The WEC obligated party must also affirm that neither the 
production segment entity impacted by the delay nor the gathering or 
transmission infrastructure entity seeking the permit contributed to 
the unreasonable delay.
    The EPA requires this information for the verification of exemption 
eligibility and of exempted emission quantity. Reported information 
will be used to conduct verification as discussed in section III.A.4., 
and reported information, records and other information as applicable 
will be used

[[Page 5336]]

to conduct any auditing that occurs under section III.E.1.
    The EPA seeks comment on the reporting and recordkeeping 
requirements for the exemption for unreasonable delay in environmental 
permitting. We seek comment on whether additional information should be 
collected or retained to allow for verification of the quantity of 
emissions eligible for the exemption.
2. Regulatory Compliance Exemption Under CAA Section 136(f)(6)
    CAA section 136(f)(6) establishes a regulatory compliance exemption 
for subpart W facilities that are ``subject to and in compliance with 
methane emissions requirements pursuant to subsections (b) and (d) of 
section 111'' upon an Administrator determination that the criteria at 
CAA section 136(f)(6)(A) have been met. In this action, the EPA is 
proposing: when the Administrator determinations will be made; the time 
at which the regulatory compliance exemption would become available to 
eligible facilities; the process for how the Administrator 
determinations will be made; how to interpret CAA section 136(f)(6)(A) 
to govern the interaction between WEC applicable facilities and CAA 
section 111(b) affected facilities and CAA section 111(d) designated 
facilities (collectively referred to in this preamble as ``CAA section 
111(b) and (d) facilities'') for the purposes of the regulatory 
compliance exemption; how ``compliance'' with the methane emissions 
requirements promulgated under CAA sections 111(b) and (d) will be 
defined for the purposes of the regulatory compliance exemption; 
reporting requirements for the regulatory compliance exemption; and the 
process for resumption of the WEC pursuant to CAA section 136(f)(6)(B) 
if the criteria for the regulatory compliance exemption are no longer 
met.
    The EPA believes the Congressional intent of this exemption was 
twofold: (1) to be implemented such that the WEC acts as a bridge to 
full implementation of the Final NSPS OOOOb and EG OOOOc by encouraging 
methane reductions in the near term while state plans are being 
developed, and thereafter exempting from the charge facilities that are 
in compliance with the requirements pursuant to the final NSPS OOOOb 
and EG-OOOOc-implementing state and Federal plans,\31\ and (2) to 
encourage timely implementation of requirements in the final NSPS OOOOb 
and EG OOOOc-implementing state and Federal plans in order to ensure 
that those requirements achieve meaningful emissions reductions. The 
EPA's proposed approach for implementing the regulatory compliance 
exemption is based on a plain reading of the statutory text in CAA 
section 136(f)(6). The EPA strives to create a program that is 
straightforward to implement and enforce.
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    \31\ Under the Tribal Authority Rule (TAR), eligible Tribes may 
seek approval to implement a plan under CAA section 111(d) in a 
manner similar to a state. See 40 CFR part 49, subpart A. Tribes 
may, but are not required to, seek approval for treatment in a 
manner similar to a state for purposes of developing a Tribal 
implementation plan (TIP) implementing the EG codified in 40 CFR 
part 60, subpart OOOOc. The TAR authorizes Tribes to develop and 
implement their own air quality programs, or portions thereof, under 
the CAA. However, it does not require Tribes to develop a CAA 
program. Tribes may implement programs that are most relevant to 
their air quality needs. If a Tribe does not seek and obtain the 
authority from the EPA to establish a TIP, the EPA has the authority 
to establish a Federal CAA section 111(d) plan for designated 
facilities that are located in areas of Indian country. A Federal 
plan would apply to all designated facilities located in the areas 
of Indian country covered by the Federal plan unless and until the 
EPA approves a TIP applicable to those facilities. In this proposal, 
all uses of the phrase ``state and Federal plans'' are intended to 
include any Tribal plans, to the extent that any Tribal plans are 
developed to implement EG OOOOc.
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    The EPA interprets the intent of the WEC to be to incentivize 
reduction of methane emissions across the oil and gas industry. For 
industry segments not covered by NSPS OOOOb/EG OOOOc, the WEC 
incentivizes, but does not require, early and sustained emissions 
mitigation activity. For WEC applicable facilities in industry segments 
that are covered by NSPS OOOOb/EG OOOOc, the WEC incentivizes, but does 
not require, methane emissions reductions earlier than may otherwise be 
required pursuant to NSPS OOOOb and EG OOOOc-derived state and Federal 
plans. Once those requirements are in effect, the EPA believes the 
purpose of the regulatory compliance exemption is to provide relief 
from the WEC to owners or operators that are fully complying with those 
requirements, and to broadly encourage compliance. This structure 
ensures that there is an incentive (or requirement) for methane 
emission reductions from new and existing sources in place at all 
times, while also avoiding regulation of the same emissions under both 
the WEC and the NSPS OOOOb and EG OOOOc-implementing state and Federal 
plans once the regulatory compliance exemption becomes available.
    The EPA expects that, as CAA section 111(b) and (d) facilities 
implement and comply with the methane emissions requirements of NSPS 
OOOOb and EG OOOOc-implementing state and Federal plans, many of the 
WEC applicable facilities that contain those emissions sources subject 
to NSPS OOOOb and EG OOOOc-derived state and Federal plans would be 
expected to fall below the waste emissions thresholds, and thus not be 
subject to the WEC. However, the regulatory compliance exemption 
recognizes that certain WEC applicable facilities may remain above the 
waste emissions thresholds even after implementation of the 
requirements in the final NSPS OOOOb and approved state and Federal 
plans under EG OOOOc; the regulatory compliance exemption would shield 
such owners or operators that are in compliance with those requirements 
from additional regulation under the WEC.
    Congress provided that the regulatory compliance exemption would 
only come into effect after ``(i) methane emissions standards and plans 
pursuant to subsections (b) and (d) of section 111 have been approved 
and are in effect in all States with respect to the applicable 
facilities'' and ``(ii) compliance with the requirements described in 
clause (i) will result in equivalent or greater emissions reductions as 
would be achieved by [the NSPS OOOOb/EG OOOOc 2021 Proposal], if such 
rule had been finalized and implemented.'' The EPA's understanding of 
these provisions is that Congress intended to provide an incentive for 
states to move promptly in adopting their plans, and to encourage those 
plans to achieve meaningful emissions reductions. These two drivers are 
manifested in the Administrator determinations that must be made before 
the regulatory compliance exemption becomes available: the first 
Administrator determination, per CAA section 136(f)(6)(A)(i), that the 
final NSPS OOOOb and all EG OOOOc-implementing state and Federal plans 
are ``approved and in effect''; and the second Administrator 
determination, per section 136(f)(6)(A)(ii), that the emissions 
reductions achieved by these requirements are equal to or greater than 
the reductions that would have been achieved by the NSPS OOOOb/EG OOOOc 
2021 Proposal, had that rule been finalized and implemented as proposed 
(the ``equivalency determination''). These requirements mean that if 
the final NSPS OOOOb or EG OOOOc-implementing state or Federal plans 
are delayed, or the requirements therein are collectively less 
stringent than those in the NSPS OOOOb/EG OOOOc 2021 Proposal, the 
exemption would not be available and WEC applicable facilities that 
exceed

[[Page 5337]]

the waste emissions threshold would not be eligible for the regulatory 
compliance exemption from the WEC until the conditions are met.
    Here, we summarize the proposed approach for the regulatory 
compliance exemption. Elements of the proposal, other options 
considered, and requests for comment are discussed in more detail in 
the sections below.
    The EPA is proposing that the prerequisite Administrator 
determinations for the regulatory compliance exemption would be made 
after all state and Federal plans pursuant to CAA section 111(d) are 
approved and in effect. Separate from the timing of the Administrator 
determinations, the WEC program must establish when the regulatory 
compliance exemption becomes available at the facility level (i.e., 
when eligible facilities can be exempted from the WEC), by defining 
when WEC applicable facilities that are subject to methane emissions 
requirements pursuant to NSPS OOOOb and EG OOOOc-implementing state and 
federal plans are in compliance with those requirements. The EPA 
believes that the regulatory compliance exemption is intended to 
provide relief from the WEC when the requirements in the final NSPS 
OOOOb and EG OOOOc-implementing state and Federal plans are in effect 
in all states. In this interest, the EPA is proposing that WEC 
applicable facilities would be eligible for the regulatory compliance 
exemption as soon as the Administrator determinations have been made, 
rather than when the applicable requirements in state and Federal plans 
are fully implemented. Thus, under the EPA's proposed approach, the 
regulatory compliance exemption would become available to facilities as 
soon as the Administrator determinations are made under CAA section 
136(f)(6)(A)(i) and (ii).
    The EPA is also proposing further elements of the process for the 
Administrator determinations under CAA section 136(f)(6)(A)(i) and 
(ii), including establishing the relative points of comparison for the 
equivalency determination, in order to ensure that those elements align 
with the statutory requirements. Because the Administrator 
determinations cannot be made until all plans are approved and in 
effect, and because the timing for both Administrator determinations is 
aligned, the EPA proposes that two the determinations be made together 
via a single future administrative action.
    The EPA is proposing that a WEC applicable facility's eligibility 
for the regulatory compliance exemption would be based on the 
compliance status of all of the CAA section 111(b) and (d) facilities 
contained within that WEC applicable facility. To be eligible for the 
exemption, the EPA proposes that all of the regulated emissions sources 
must be in full compliance with their respective methane emissions 
requirements under the NSPS and EG-implementing state and Federal 
plans.
    The EPA is also proposing reporting requirements for the regulatory 
compliance exemption. In order to reduce the burden on industry, the 
EPA proposes that only WEC applicable facilities that are eligible for 
the exemption would be required to report all associated data elements. 
Finally, the EPA is proposing how access to the regulatory compliance 
exemption would be removed for all WEC applicable facilities if the 
criteria associated with the Administrator determinations were no 
longer met. The EPA's proposed approach for removing access to the 
exemption mirrors the conditions that must be met in order for it to 
become available.
a. Timing for Regulatory Compliance Determinations
    Before the regulatory compliance exemption becomes available to 
facilities, CAA section 136(f)(6)(A) requires determinations to be made 
by the Administrator that (1) ``methane emissions standards and plans 
pursuant to subsections (b) and (d) of section 111 have been approved 
and are in effect in all States with respect to the applicable 
facilities'' and (2) that ``compliance with the requirements described 
in clause (i) will result in equivalent or greater emissions reductions 
as would be achieved by the [NSPS OOOOb/EG OOOOc 2021 Proposal], if 
such rule had been finalized and implemented.'' The EPA believes that 
Congress intended these prerequisites to exemption availability to 
encourage timely implementation of the requirements in the final NSPS 
and state and Federal plans and to ensure that those requirements 
achieve meaningful emissions reductions.
    The first Administrator determination is related to the timing of 
final methane emissions standards under CAA section 111(b) and state 
and Federal plans pursuant to an EG issued under CAA section 111(d). 
The EPA proposes to interpret the language in CAA section 
136(f)(6)(A)(i) to mean that this temporal requirement is only met when 
both (1) emission standards for new sources under CAA section 111(b) 
are promulgated and in effect and (2) all state plans for existing 
sources pursuant to an EG issued under CAA section 111(d) have been 
approved by the EPA and are in effect. As to the latter element, the 
EPA also proposes to interpret the reference to ``plans pursuant to 
subsection. . . (d) of section 111'' to include the promulgation of a 
Federal plan where the EPA determines that one or more states have 
failed to submit an approvable state plan, as that is the only way a 
plan pursuant to CAA section 111(d) would take effect in those states. 
The EPA further proposes to interpret ``all states'' in CAA section 
136(f)(6)(A)(i) to mean that every state with an applicable facility 
(i.e., all states with subpart W facilities containing CAA section 
111(b) or (d) facilities) must have an approved plan (state or Federal) 
before the determination can be made. Accordingly, because the 
emissions standards for new sources under CAA section 111(b) will be 
finalized before the submittal of state plans for existing sources 
under CAA section 111(d), approval of the final state (or Federal) plan 
for states with designated facilities would determine the timing for 
when the determination could be made under the proposed approach. The 
EPA proposes that this determination would be made after all CAA 
section 111(d) plans (i.e., state or Federal plans) have been approved 
and are in effect. The EPA believes that the proposed approach and 
interpretation of ``all states'' is aligned with a plain reading of the 
statutory text. In particular, the EPA notes the relationship between 
the use of the singular in section 136(f)(6)(A), directing the EPA to 
make ``a determination'', and the requirements outlined in 
136(f)(6)(A)(ii) and (ii), providing that this determination is 
dependent on EPA finding that (1) standards and plans ``have been 
approved and are in effect in all states'' and that (2) compliance with 
the standards and plans ``will result in equivalent or greater 
emissions reductions as would be achieved by the [2021] proposed rule. 
. .'' \32\ The text strongly indicates that the EPA must make one 
determination after all standards and plans are in place in all states 
in order to make the exemption available, and further that the 
determination cannot be made until standards and plans are in place in 
all states because the equivalency determination must be made on a 
nationwide scale.\33\
---------------------------------------------------------------------------

    \32\ 42 U.S.C. 7436(f)(6)(A).
    \33\ Note that while the EPA believes that the statute instructs 
us to make a determination after the plans are collectively in place 
(rather than making multiple state-by-state determinations), that 
does not preclude the EPA from reviewing and revising the 
determination if a standard or plan is later revised, to ensure that 
the conditions of section 136(f)(6)(A) are still met, consistent 
with the resumption of charge language in section 136(f)(6)(B).

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[[Page 5338]]

    The EPA considered an alternative approach for the determination 
that methane emissions standards and plans have been approved and are 
in effect in all states. This alternative would involve a determination 
for methane emissions standards after the promulgation of final 
emissions standards for CAA section 111(b) facilities and then 
determinations on a state-by-state basis as each state plan containing 
emissions standards for CAA section 111(d) facilities were submitted 
and approved by the EPA (or a Federal plan was promulgated where a 
state did not submit an approvable plan). The EPA believes that this 
state-by-state approach is inconsistent with a plain reading of CAA 
section 136(f)(6)(A)(i), which mandates that emissions standards and 
plans must be approved and in effect in all states with respect to the 
applicable facilities (i.e., all states with subpart W facilities 
containing CAA section 111(b) or (d) facilities). The EPA requests 
comment on the proposed approach and an alternative approach that would 
make determinations on a state-by-state basis as each state plan was 
approved.
    The second determination that must be made before the regulatory 
compliance exemption becomes available is whether the final ``methane 
emissions standards and plans'' provide equivalent or greater emissions 
reductions than would have been achieved by the NSPS OOOOb/EG OOOOc 
2021 Proposal, had that proposal been finalized and implemented as 
proposed. Based on a plain reading of the statutory text, because plans 
pursuant to CAA section 111(d) will not be finalized for several years, 
the EPA cannot propose an equivalency determination in this action. 
Instead, we propose that the equivalency determination will be made via 
an administrative action after all CAA section 111(d) plans (i.e., 
state or Federal plans) have been approved. This proposed timing would 
allow evaluation of the emissions reductions achieved by the final NSPS 
and by all final state and Federal plans.
    The EPA also assessed making the equivalency determination for CAA 
section 111(b) affected facilities before making it for CAA section 
111(d) designated facilities. In this proposal, the EPA interprets CAA 
section 136(f)(6)(ii) as requiring a comparison of the emissions 
reductions that will be achieved by the final NSPS OOOOb/EG OOOOc and 
the reductions that would have been achieved by the NSPS OOOOb/EG OOOOc 
2021 Proposal if finalized as proposed. Separate equivalency 
determinations for CAA section 111(b) facilities and CAA section 111(d) 
facilities would not provide for a comparison of the total emissions 
reductions achieved by both rules, and therefore the EPA believes that 
an approach with separate equivalency determinations would be 
inconsistent with a plain reading of the statutory text. Further, 
because both determinations must occur before the exemption becomes 
available, and because under the proposed approach the determination 
required by CAA section 136(f)(6)(i) would occur after all plans are 
approved and in effect, there would be no practical reason for making 
the equivalency determination for CAA section 111(b) facilities before 
making it for CAA section 111(d) facilities. Finally, the only purpose 
for making the equivalency determination for CAA section 111(b) 
facilities before CAA section 111(d) facilities would be in support of 
an approach that would make the regulatory compliance exemption 
available to CAA section 111(b) facilities before CAA section 111(d) 
facilities. As discussed below in section II.D.2.b of this preamble, 
such an approach would not align with other elements of this proposal, 
would not be aligned with the statutory text, and would not be 
technically feasible. The EPA requests comment on this alternative 
approach.
b. Timing of Regulatory Compliance Exemption Availability
    Separate from the timing of the Administrator determinations, the 
WEC program must also establish when the regulatory compliance 
exemption will become available for facilities. Different states will 
have different start dates and in some cases, phased-in requirements, 
in state or federal plans under 111(d), resulting in some facilities 
being in compliance with the methane emissions requirements pursuant to 
CAA section 111(b) and (d) before others. The EPA believes the 
inclusion of the regulatory compliance exemption at CAA section 
136(f)(6)allows for relief from the WEC when the requirements in the 
final NSPS and state and Federal plans are in effect. The EPA therefore 
proposes that the regulatory compliance exemption would become 
available to all applicable facilities meeting the criteria when the 
Administrator determinations required by CAA section 136(f)(6)(A)(i) 
and (ii) have both been made. Both determinations are required before 
the exemption becomes available, and the determination under CAA 
section 136(f)(6)(A)(i) would indicate that the requirements 
promulgated under CAA sections 111(b) and (d) have been approved and 
are in effect. Because the availability of the exemption is linked to 
the CAA section 136(f)(6)(A)(i) and (ii) determinations, which the EPA 
is proposing could only be made after all states with an applicable 
facility have an approved state or Federal plan in effect, the EPA is 
proposing that the exemption would become available to all eligible WEC 
applicable facilities in all states at the same time. Moreover, because 
methane emissions standards for CAA section 111(b) facilities would be 
expected to come into effect earlier than those required for CAA 
section 111(d) facilities in state or Federal plans, the timing for 
exemption availability would be largely driven by the approval and 
effective date for the final state or Federal plan (i.e., the last 
state with CAA section 111(d) facilities to have a plan approved and in 
effect).
    The EPA believes the proposed approach is consistent with the 
statutory text. CAA section 136(f)(6)(A) states that charges shall not 
be imposed on an applicable facility ``that is subject to and in 
compliance with methane emissions requirements pursuant to subsections 
(b) and (d) of section 111.'' In order to receive the exemption, all 
CAA section 111(b) and (d) facilities contained within a WEC applicable 
facility would need to demonstrate compliance, as discussed in section 
II.D.2.f. of this preamble.
    This proposal makes the exemption available upon adoption of all 
plans pursuant to CAA section 111(d) and the issuance of the 
Administrator's findings under CAA section 136(f)(6)(A). The EPA 
proposes that the exemption be available as soon as all state or 
federal plans are in effect, because facilities can be in compliance 
with the requirements in plan even if full implementation of those 
requirements is not required until a future date. Provided that 
facilities subject to the WEC are in compliance with OOOOb requirements 
and the requirements in EG OOOOc-implementing plans, the proposed 
approach also allows such facilities to benefit from the regulatory 
compliance exemption much earlier than the alternative, described 
below, of making the regulatory compliance exemption available only 
once applicable compliance deadlines have passed.
    The EPA notes that implementation of the requirements included in 
state or Federal plans may not be mandated immediately upon the date at 
which the plan goes into effect. In other words, the plans may include 
compliance

[[Page 5339]]

schedules with compliance dates that occur at a future date after plan 
approval, and such requirements could be implemented over multiple 
compliance dates in a phased manner or include deadlines for various 
increments of progress. It is therefore possible for CAA section 111(d) 
facilities to be in compliance with the methane emissions requirements 
in a plan even if not all compliance dates included in the plan have 
come to pass. For example, if an approved state plan were to require a 
specific type of designated facilities to install emissions controls 
within a year of the effective date of the state plan, those facilities 
would be considered in compliance with those requirements for that 
first year. By providing the exemption as soon as the Administrator's 
determinations are made after state or Federal plans are approved and 
in effect rather than when the requirements in those plans must be 
implemented, the proposed approach would provide relief from the WEC 
once CAA section 111(d) facilities are effectively subject to federally 
enforceable methane emissions requirements pursuant to CAA section 111. 
The EPA requests comment on the proposed approach of making the 
regulatory compliance exemption available to all WEC applicable 
facilities at the time when the two determinations required by CAA 
section 136(f)(6)(A) have been made.
    The EPA considered alternative approaches in developing this 
proposal for implementing the regulatory compliance exemption but found 
they would not be consistent with the statutory text, would be more 
challenging to implement, would unfairly advantage specific facilities 
and companies, or would not be technically feasible.
    First, the EPA considered an approach that would make the exemption 
available to WEC applicable facilities meeting the criteria at a state-
by-state level as the plan pursuant to CAA section 111(d) for each 
state was approved and became effective. For WEC applicable facilities 
that span multiple states, the exemption would be available when plans 
for all states in which the facility is located were approved and in 
effect. This alternative approach would likely make the exemption 
available earlier for certain WEC applicable facilities compared to the 
proposed approach, which would not make the exemption available until 
plans are approved and in effect in all states. The EPA believes that 
making the regulatory compliance available at a state-by-state level is 
inconsistent with the statutory text. As discussed in section II.D.2.a. 
of this preamble, the EPA's interpretation of CAA section 136(f)(6)(A) 
in this proposal is that neither of the determinations that are 
prerequisites to the regulatory compliance exemption's availability 
could be made until plans for CAA section 111(d) facilities have been 
approved and are in effect for all states. Based on this 
interpretation, it would not be possible for the exemption to become 
available on a state-by-state basis as state plans were approved and 
became effective because the prerequisite determinations could not 
occur until all state plans were approved and in effect. The EPA also 
believes the proposed approach will simplify implementation and 
administration of the regulatory compliance exemption compared to an 
approach in which the exemption would become available to states at 
different times. Further, a state-by-state application of the exemption 
could unfairly advantage and disadvantage WEC applicability facilities 
or companies based on their geographic location. WEC obligations for 
operations in states that take longer to develop state plans could be 
higher than those in states that are able to develop and have plans 
approved earlier, and thus have access to the exemption. Conversely, 
the proposed approach of making the exemption available to all states 
at the same time would be equitable and provide the industry with 
better regulatory certainty. The EPA requests comment on making the 
regulatory compliance exemption available on a state-by-state basis 
based on the finalization of plans for individual states.
    Second, the EPA considered an approach that would make the 
regulatory compliance exemption available to WEC applicable facilities 
meeting the criteria when the methane requirements for all CAA section 
111(b) and (d) facilities have been fully implemented. Under this 
alternative approach, WEC applicable facilities would only become 
eligible for the regularly compliance exemption once the compliance 
dates for the NSPS and the state and Federal plans have passed. Because 
the compliance deadlines under the final EG OOOOc may occur at some 
point after the timeline for state plan approval and issuance of a 
Federal plan, this alternative approach would make the regulatory 
compliance exemption available later than under the proposed approach. 
This would require the EPA to interpret the phrase ``subject to and in 
compliance with methane emissions requirements'' in CAA section 
136(f)(A) to mean that the exemption from the charge is available only 
after all of the requirements for CAA section 111(d) facilities have 
been fully implemented. In other words, the EPA would read ``in 
compliance with methane emissions requirements'' to mean that all 
compliance dates in the NSPS and the state and Federal plans have 
passed. That might serve to give independent effect to both elements of 
the statutory phrase ``subject to and in compliance with'', but the EPA 
believes that this alternative approach is not as well aligned with the 
statutory directive. This is because compliance with the standards may 
occur at different points in time, both across the NSPS and the state 
and Federal plans, and even within standards that have phased 
compliance requirements. This interpretation may have the result of 
delaying availability of the regulatory compliance exemption for many 
years, even as facilities are otherwise complying with all applicable 
methane emissions requirements, thus extending the period for which 
many oil and gas operations would be subject to concurrent regulation 
under WEC and CAA section 111. Rather, the EPA proposes to conclude 
that CAA section 111(b) and (d) facilities can be considered to be in 
compliance with all applicable methane emissions requirements, even 
prior to the final compliance deadlines, for purposes of the regulatory 
compliance exemption. While the EPA is not proposing that the exemption 
would become available when the requirements of all state and Federal 
plans are fully implemented rather than when all state and Federal 
plans have been approved and are in effect, the agency requests comment 
on whether such an approach would be legally and practically justified.
    Third, the EPA considered an approach that would make the 
regulatory compliance exemption available to WEC applicable facilities 
meeting the criteria at a state-by-state level as the final compliance 
deadline in a state or Federal plan for CAA section 111(d) facilities 
was reached. Under this alternative approach, WEC applicable facilities 
in a given state would have access to the exemption upon the final 
compliance date for CAA section 111(d) facilities in that state. 
Because state and Federal plans may establish different compliance 
timelines for CAA section 111(d) facilities, this approach could make 
the exemption available to states at different times. For WEC 
applicable facilities that span multiple states, the exemption would be 
available when the final compliance date passed in all

[[Page 5340]]

states in which the facility is located. As with the alternative 
approach that would make the exemption available after the final 
compliance deadline for CAA section 111(d) facilities had passed in all 
states, the EPA does not believe an approach that provides the 
exemption at a state-by-state level based on compliance dates is as 
consistent with the statutory text and purpose of the exemption for the 
reasons discussed in the prior paragraph. The EPA requests comment on 
an approach that would make the exemption available at a state-by-state 
level based on each state's final compliance deadline for CAA section 
111(d) facilities.
    The EPA also assessed an approach that would make the regulatory 
compliance exemption available to CAA section 111(b) facilities before 
CAA section 111(d) facilities. Because compliance with emission 
standards for CAA section 111(b) affected facilities generally apply 
upon the effective date of the final NSPS and would be required before 
emission standards for CAA section 111(d) designated facilities are 
fully implemented (once state or Federal plans are finalized and in 
effect), there would likely be several years between compliance with 
methane emissions requirements for CAA section 111(b) and (d) 
facilities. The EPA rejected this approach for this proposal, however, 
based on a plain reading of the statutory text. First, as discussed in 
section II.D.2.e. of this preamble, the exemption is applied to an 
entire WEC applicable facility, not the CAA section 111(b) and (d) 
facilities within that WEC applicable facility, and therefore 
individual CAA section 111(b) or (d) facilities within a WEC applicable 
facility cannot be exempted. Second, CAA section 136(f)(6)(A) states 
that waste emission charges shall not be imposed ``on an applicable 
facility that is subject to and in compliance with methane emissions 
requirements pursuant to subsections (b) and (d) of section 111.'' The 
EPA believes that a plain reading of this text indicates that 
compliance with regulations pursuant to both CAA section 111(b) and (d) 
must be achieved before the exemption becomes available, and that the 
statute therefore does not, by its terms, permit application of the 
exemption to CAA section 111(b) facilities before it becomes available 
to CAA section 111(d) facilities. As discussed in section II.D.2.a. of 
this preamble, the EPA proposes to make the determinations required by 
CAA section 136(f)(6)(A)(i) and (ii) after all state or Federal plans 
have been approved and are in effect. Because the determinations that 
are required for the exemption to become available would not be made 
separately for CAA section 111(b) facilities and CAA section 111(d) 
facilities, the exemption would not be available to CAA section 111(b) 
facilities before CAA section 111(d) facilities under the proposed 
approach.
    Further, even assuming that this statutory text allowed for some 
ambiguity, there are practical limitations to implementing the 
regulatory exemption in a phased manner for CAA section 111(b) and (d) 
facilities. The WEC calculations are based on methane emissions and 
natural gas or oil throughput data for subpart W facilities that may 
contain both CAA section 111(b) and (d) facilities. Because reporting 
under subpart W does not distinguish between CAA section 111(b) and (d) 
facilities, there is currently no practical means of implementing a 
phased implementation of the regulatory compliance exemption. Revising 
the subpart W reporting requirements to make such distinctions would 
significantly increase the reporting complexity and burden for the oil 
and gas industry and would not be possible for certain emissions 
sources due to different definitions of individual emissions source 
types in subpart W and at CAA section 111(b) and (d) facilities. 
Further, while it may be feasible to distinguish emissions from new and 
existing sources for certain emission source categories, there is no 
means to distinguish natural gas throughput from CAA section 111(b) and 
(d) facilities at subpart W facilities that contain both CAA section 
111(b) and (d) facilities.
c. Emissions Year in Which Exemption Takes Effect
    While the data collected under subpart W for the purposes of WEC 
calculation are reported on a calendar-year basis (i.e., a reporting 
year is a calendar year), the date at which all of the criteria for the 
regulatory compliance exemption will be met is not yet known and could 
fall at any point in the course of a reporting year. The EPA is 
proposing that the regulatory exemption will take effect in the 
reporting year in which the required conditions are met. For example, 
if all exemption requirements are met in June 2027, all eligible 
facilities meeting the proposed compliance requirements discussed in 
section II.D.2.f. of this preamble would be exempt from the WEC for the 
entire 2027 reporting year. The proposed approach is aligned with the 
EPA's interpretation that the regulatory compliance exemption is 
intended to prevent WEC applicable facilities from being subject to the 
WEC when their constituent CAA section 111(b) and (d) facilities are in 
compliance with their applicable standards. The EPA requests comment on 
the proposed approach, as well as an approach in which the regulatory 
compliance exemption became effective for eligible facilities in the 
next calendar year after which all required conditions are met (e.g., 
if requirements are met in October 2027, the exemption would come into 
effect for the 2028 reporting year). The EPA also requests comment on 
an approach that would apply the regulatory exemption for a portion of 
the reporting year based on when all exemption requirements were met, 
and how reported emissions and throughput data could be quantified, 
such as through prorating.
d. Approach for Regulatory Compliance Determinations
    In this action, the EPA is proposing certain elements related to 
the approach for the CAA section 136(f)(6)(A) Administrator 
determinations that must occur before the regulatory compliance 
exemption becomes available. The EPA is proposing that both 
determinations would be made simultaneously via a future administrative 
action. For the equivalency determination, the EPA is proposing the 
geographic scale at which the equivalency determination would be 
conducted and the specific elements that would be compared. The EPA 
proposes to address all other elements (e.g., cumulative versus year-
by-year) of the equivalency determination in a future administrative 
action when the analysis is conducted.
    The EPA proposes that when the criteria for both determinations are 
met, the determinations would be made through a single administrative 
action. As discussed in section II.D.2.a. of this preamble, under the 
proposed approach neither determination could be made until all state 
and Federal plans pursuant to CAA section 111(d) have been approved and 
are in effect. Because the timing for both determinations would be 
aligned, the EPA believes that making both determinations via a single 
administrative action will facilitate timely access to the regulatory 
compliance exemption after the CAA section 136(f)(6)(A)(i) and (ii) 
requirements have been met. The EPA requests comment on the proposed 
approach for making both determinations via a single future 
administrative action, as well as on alternative approaches for making 
the determinations.
    Section 136(f)(6)(A)(ii) of the CAA requires an Administrator 
determination

[[Page 5341]]

that compliance with the requirements in the final CAA section 111(b) 
and (d) rules ``will result in equivalent or greater emissions 
reductions as would be achieved by the [NSPS OOOOb/EG OOOOc 2021 
Proposal], if such rule had been finalized and implemented.'' The EPA 
is proposing to conduct the analysis for the purposes of this 
equivalency determination at a national level, comparing the national-
level emissions reductions that would have been achieved under the NSPS 
OOOOb/EG OOOOc 2021 Proposal (if finalized as proposed) against those 
that will be achieved upon implementation of the final NSPS OOOOb/EG 
OOOOc.
    The EPA believes that a national evaluation is the most appropriate 
geographic scale for the purposes of the equivalency determination. The 
primary concern for the emissions reductions achieved by the NSPS 
OOOOb/EG OOOOc in the context of the WEC regulatory compliance 
exemption are methane emissions. Because the climate impacts of these 
emissions are dependent on their aggregate quantity rather than where 
they occur, a national-level evaluation will provide an appropriate 
comparison of the overall impact of the reductions that would have been 
achieved under the NSPS OOOOb/EG OOOOc 2021 Proposal and those that 
will be achieved upon implementation of the final NSPS OOOOb and state 
and Federal plans implementing OOOOc. The EPA also considers a national 
evaluation to be consistent with the statutory text in CAA section 
136(f)(6)(A)(ii), which requires the Administrator's determination to 
be based on ``compliance with the requirements described in clause 
(i),'' where clause (i) describes the collective ``methane emissions 
standards and plans'' required by CAA sections 111(b) and (d).
    The EPA assessed alternative approaches that would conduct the 
equivalency determination at the state-by-state level (i.e., each state 
would need to demonstrate equivalent or greater emissions reductions) 
and at both the national and state-by-state levels. However, the EPA is 
not proposing an approach that would conduct the equivalency at the 
state-by-state level because the EPA believes that this approach is 
less consistent with the statutory text and purpose. Determinations for 
individual states would not indicate if the emissions reductions that 
will be achieved by the final NSPS and state and Federal plans are 
equivalent or greater than the reductions that would have been achieved 
by the NSPS OOOOb/EG OOOOc 2021 Proposal, had that rule been finalized 
and implemented. In other words, if the EPA were to make determinations 
for individual states and make the exemption available on a state-by-
state basis, that could result in not achieving emission reductions 
equivalent to the NSPS OOOOb/EG OOOOc 2021 Proposal, thus undermining 
Congress' intent in drafting this provision to incentivize a minimum 
level of methane emission reductions via the CAA section 111(b) and (d) 
regulations. The EPA requests comment on the proposed approach of 
conducting the equivalency determination at the national scale. The EPA 
requests comment on conducting the equivalency determination at other 
geographic scales, such as a state-by-state level, as well as an 
approach that would require an equivalency determination at both the 
national and state-by-state levels.
    The EPA also considered an alternative approach that would conduct 
the equivalency analysis at a source-by-source level (at either a 
national or state-by-state scale). Under this alternative approach, the 
EPA would compare the reductions achieved by individual sources under 
the NSPS OOOOb/EG OOOOc 2021 Proposal, had that rule be finalized and 
implemented, and the final NSPS OOOOb/EG OOOOc. As described above, the 
climate impacts of methane emissions are based on their aggregate 
quantity, and it is that quantity, therefore, that is necessary for 
conducting the equivalency determination. Within the specific context 
of the equivalency determination, it does not matter if the emissions 
reductions achieved by an individual source under the final NSPS OOOOb/
EG OOOOc achieves fewer reductions than it would have under the NSPS 
OOOOb/EG OOOOc 2021 Proposal, as long as the total emissions reductions 
achieved by implementation of the final NSPS OOOOb and EG OOOOc-derived 
state or federal plans across all sources are equivalent or greater 
than those that would have been achieved across all sources by the NSPS 
OOOOb/EG OOOOc 2021 Proposal. The EPA therefore believes that it is not 
reasonable to conduct the equivalency analysis on a source-by-source 
level and such an approach is not required by the statutory text. 
However, the EPA requests comment on using a source-by-source approach 
for the equivalency determination and requests comment on how such an 
analysis could be conducted.
    Because the NSPS OOOOb/EG OOOOc 2021 Proposal was not itself a 
final rule at the time Congress enacted this Waste Emissions Charge 
program, no new source emissions standards or emission guidelines had 
been finalized for CAA section 111(b) and (d) facilities based on the 
NSPS OOOOb/EG OOOOc 2021 Proposal, no requirements had been finalized 
for what constitutes an approvable state plan, and no states had 
submitted state plans pursuant to such hypothetical finalized 
requirements. As such, the EPA proposes to use the standards proposed 
in NSPS OOOOb and the presumptive standards proposed in EG OOOOc as the 
basis for evaluating emissions reductions that would have been achieved 
had the NSPS OOOOb/EG OOOOc 2021 Proposal been finalized and 
implemented. In other words, the EPA understands the inclusion of the 
NSPS OOOOb/EG OOOOc 2021 Proposal as the baseline for the equivalency 
demonstration to mean that Congress intended for the EPA to assume, for 
purposes of this analysis, that the proposed standards were finalized 
as drafted in the NSPS OOOOb/EG OOOOc 2021 Proposal and implemented 
nationwide. Further, because Congress directs the EPA to compare the 
emissions that would have been achieved if the NSPS OOOOb/EG OOOOc 2021 
Proposal were finalized and implemented against actual CAA section 
111(b) and (d) standards once these are finalized and in effect, the 
EPA believes that Congress must have meant the EPA to assume that the 
NSPS OOOOb/EG OOOOc 2021 Proposal was finalized and implemented as 
proposed, which is the only way to use it as a point of comparison. 
Accordingly, for CAA section 111(b) facilities under the NSPS OOOOb/EG 
OOOOc 2021 Proposal, the EPA proposes to assess the reductions that 
would have been achieved had the proposed NSPS OOOOb been finalized and 
implemented. For CAA section 111(d) facilities under the NSPS OOOOb/EG 
OOOOc 2021 Proposal, the EPA proposes to assess the reductions that 
would have been achieved had the proposed emissions guidelines been 
adopted and implemented by all states as proposed.
    The EPA believes the proposed points of comparison between the NSPS 
OOOOb/EG OOOOc 2021 Proposal and the final NSPS OOOOb and final 
requirements in state and Federal plans derived from EG OOOOc for the 
equivalency is aligned with a plain reading of CAA section 
136(f)(6)(A), and with Congressional intent. The EPA requests comment 
on the proposed approach. The EPA recognizes that if the NSPS OOOOb/EG 
OOOOc 2021

[[Page 5342]]

Proposal had been finalized as proposed, the requirements for CAA 
section 111(d) facilities, and the emissions reductions associated with 
those requirements, would have been based on approved state or Federal 
plans. In those plans, it is possible that some states may have set 
different standards of performance than the presumptive standards 
proposed in EG OOOOc based on a provision of CAA section 111(d)(1) 
permitting states to ``take into consideration, among other factors, 
the remaining useful life of a source.'' (The EPA refers to this 
provision as the ``remaining useful life and other factors'' provision, 
or RULOF.) The EPA regulations at 40 CFR part 60 subpart Ba permit 
states to consider several factors to, with an adequate demonstration, 
establish standards less stringent than the degree of emission 
limitation otherwise required by an EG. In such circumstances, the 
emissions reductions achieved by those state plans would have been less 
than if the state plans had adopted and implemented the presumptive 
standards in the final emissions guidelines, had they been finalized. 
However, because state plans were never developed pursuant to the NSPS 
OOOOb/EG OOOOc 2021 Proposal, there is no means of reasonably 
estimating the requirements that may have been included in those state 
plans and what emissions reductions they would have achieved. The text 
also counsels against making RULOF assumptions in this case. Because 
Congress directs the EPA to compare the emissions that would have been 
achieved if the NSPS OOOOb/EG OOOOc 2021 Proposal were ``finalized and 
implemented'' against actual CAA section 111(b) and (d) standards once 
these are ``approved and in effect,'' the EPA believes that Congress 
meant the Agency to assume that the NSPS OOOOb/EG OOOOc 2021 Proposal 
was finalized and implemented as proposed, because that will allow for 
comparison with emissions reductions achieved under the final CAA 
section 111(d) plans, which may differ from the proposal in a variety 
of ways, including as a result of RULOF analysis. It is also reasonable 
to infer that Congress wanted to guarantee the level of reductions 
(i.e., ``equivalent or greater'' \34\ than expected by the NSPS OOOOb/
EG OOOOc 2021 Proposal) that would ultimately be achieved by the final 
NSPS OOOOb and EG OOOOc-derived state and Federal plans by only 
allowing for the exemption if it is determined that the Final NSPS 
OOOOb/EG OOOOc would achieve at least the level of reductions that were 
expected from the proposed rule in place at the time CAA section 136 
was written and passed. Thus, the EPA believes the intent of CAA 
section 136(f)(6)(A) is to use the proposed approach of assessing the 
reductions that would have been achieved had the proposed emissions 
guidelines in the NSPS OOOOb/EG OOOOc 2021 Proposal been adopted and 
implemented by all states as proposed. The EPA requests comment on 
other approaches that could be used to estimate the emissions 
reductions from CAA section 111(d) facilities had the NSPS OOOOb/EG 
OOOOc 2021 Proposal been finalized and implemented.
---------------------------------------------------------------------------

    \34\ 42 U.S.C. 7436(f)(A)(ii) (requiring a determination by the 
Administrator that ``compliance with the requirements described in 
clause (i) will result in equivalent or greater emissions reductions 
as would be achieved by [the 2021 proposal]''.)
---------------------------------------------------------------------------

    The EPA also recognizes that in the proposed approach for the 
equivalency determination, analysis of the reductions from CAA section 
111(d) facilities under the NSPS OOOOb/EG OOOOc 2021 Proposal would be 
based on universal adoption of the presumptive standards in the 
proposed emissions guidelines, while analysis of the reductions 
achieved by state and Federal plans developed pursuant to the final EG 
OOOOc would account for any states' use of the RULOF provision to set 
less stringent standards. The EPA believes the proposed approach of 
assessing the reductions achieved by final state and Federal plans is 
aligned with the statutory text and Congressional intent. CAA section 
136(f)(6)(A)(ii) states that the point of comparison for the emissions 
reductions that would have been achieved by the NSPS OOOOb/EG OOOOc 
2021 Proposal are those resulting from ``compliance with the 
requirements described in clause (i).'' CAA section 136(f)(6)(A)(i) in 
turn refers to the ``methane emissions standards and plans pursuant to 
subsections (b) and (d) of section 111.'' The EPA's proposed approach 
to use the reductions that will be achieved by approved state and 
Federal plans in the equivalency determination is based on the use of 
``plans'' in CAA section 136(f)(6)(A)(i). Further, CAA section 
136(f)(6)(A)(ii) establishes that EPA may not make the equivalency 
determination unless and until it can establish that ``compliance with 
the requirements described in clause (i) will result in equivalent or 
greater emissions reductions as would be achieved by the [NSPS OOOOb/EG 
OOOOc 2021 Proposal].'' \35\ As similarly noted above, it is reasonable 
to infer from this language that Congress intended to guarantee that a 
minimum level of emissions reduction would be achieved by 
implementation of the CAA section 111 standards before the exemption 
became available--and because application of the RULOF provision may 
result in less stringent standards, Congress could not guarantee this 
minimum level would be achieved unless the equivalency determination 
considered the reductions actually achieved by the final NSPS and the 
standards actually set in state plans, including any standards set 
pursuant to the RULOF provision.
---------------------------------------------------------------------------

    \35\ 42 U.S.C. 7436(f)(6)(A)(ii) (emphasis added).
---------------------------------------------------------------------------

    The EPA considered an approach which would compare the NSPS OOOOb/
EG OOOOc 2021 Proposal, as proposed, with the final NSPS OOOOb/EG OOOOc 
as finalized but before implementation and consideration of RULOF, but 
ultimately rejected this approach. Although this approach would be 
relatively simple to apply, not taking into account the actual 
standards adopted in the state plans cannot lead to a sound conclusion 
about whether the emission reduction target that the statute sets will 
actually be met in practice. In other words, this approach could not 
guarantee that the ``result'' of implementation of the plans will be 
equivalent reductions, as the statute requires the EPA to determine. 
Further, CAA section 136(f)(6)(A)(ii) states that ``compliance'' with 
the standards should result in equivalent emissions reductions, but in 
practice, sources are not required to comply with the EG; instead, 
sources must comply with standards later established in state or 
federal plans. For these reasons, the EPA believes that comparing the 
NSPS OOOOb/EG OOOOc 2021 Proposal with the final NSPS OOOOb/EG OOOOc as 
finalized, but before implementation, is not as well aligned with the 
statutory text and intent of Congress. The EPA requests comment on its 
proposed approach and other approaches that could be used to estimate 
the emissions reductions that will be achieved by plans pursuant to CAA 
section 111(d), including comparing the NSPS OOOOb/EG OOOOc 2021 
Proposal with the final NSPS OOOOb/EG OOOOc before implementation and 
consideration of RULOF.
    The EPA reviewed comments on this topic submitted in response to 
the NSPS OOOOb/EG OOOOc 2022 Supplemental Proposal. Those comments 
informed the EPA's proposed approach and alternative approaches. While 
those comments were considered in the development of this proposal, 
because they were submitted in response to a

[[Page 5343]]

separate rulemaking, any duplicative or additional comments on this 
topic must resubmitted in response to this proposal in order to be 
considered in the development of the final WEC rule.
e. Application of the Regulatory Compliance Exemption to Subpart W 
Facilities
    CAA section 136(f)(6)(A) states: ``[c]harges shall not be imposed 
pursuant to subsection (c) on an applicable facility that is subject to 
and in compliance with methane emissions requirements pursuant to 
subsections (b) and (d) of section 111'' upon an Administrator 
determination that ``(i) methane emissions standards and plans pursuant 
to subsections (b) and (d) of section 111 have been approved and are in 
effect in all States with respect to the applicable facilities; and 
(ii) compliance with the requirements described in clause (i) will 
result in equivalent or greater emissions reductions as would be 
achieved by the'' NSPS OOOOb/EG OOOOc 2021 Proposal.
    The EPA notes that an applicable facility in CAA section 136(d) is 
an entire site or collection of sites, each of which contains 
individual emissions sources. In contrast, the terms ``affected 
facility'' \36\ and ``designated facility'' \37\ are used by the EPA in 
the NSPS and EG regulations, respectively, to refer to an individual 
emissions source or a group of emissions sources at a site (e.g., a 
storage tank battery or a collection of pneumatic controllers) to which 
a standard applies. A single subpart W facility may contain hundreds or 
thousands of CAA section 111(b) and (d) facilities. The EPA proposes to 
interpret and implement the regulatory compliance exemption such that 
an applicable subpart W facility that contains any CAA section 111(b) 
or (d) facilities would be eligible for the exemption once all other 
criteria are met (i.e., the Administrator determinations and proposed 
compliance elements in 40 CFR 99.40). Table 3 shows the subpart W 
industry segments applicable to the WEC that may contain CAA section 
111(b) or (d) facilities. WEC applicable facilities in the offshore 
production, LNG storage, LNG import and export, and transmission 
pipeline industry segments do not contain CAA section 111(b) or (d) 
facilities under the Crude Oil & Natural Gas source category (or any 
other source category in 40 CFR part 60) and would not be eligible for 
the regulatory compliance exemption. The EPA proposes that if any 
future NSPS/EG rules are finalized such that additional industry 
segments contain CAA section 111(b) or (d) facilities, the WEC 
applicable facilities in those segments would be eligible for the 
regulatory compliance exemption.
---------------------------------------------------------------------------

    \36\ ``Affected facility'' is defined for purposes of an NSPS at 
40 CFR 60.2 to mean ``with reference to a stationary source, any 
apparatus to which a standard is applicable.''
    \37\ ``Designated facility'' is defined for purposes of an EG at 
40 CFR 60.21a to mean ``any existing facility. . . which emits a 
designated pollutant and which would be subject to a standard of 
performance for that pollutant if the existing facility were an 
affected facility.''

   Table 3--Subpart W Industry Segment and CAA Section 111(b) and (d)
                            Facility Overlap
------------------------------------------------------------------------
Subpart W industry segment subject to    May contain CAA Section 111(b)
                 WEC                         and/or (d) facilities?
------------------------------------------------------------------------
Onshore petroleum and natural gas      Yes.
 production.
Offshore petroleum and natural gas     No.
 production.
Onshore petroleum and natural gas      Yes.
 gathering and boosting.
Onshore natural gas processing.......  Yes.
Onshore natural gas transmission       Yes.
 compression.
Onshore natural gas transmission       No.
 pipeline.
Underground natural gas storage......  Yes.
LNG import and export equipment......  No.
LNG storage..........................  No.
------------------------------------------------------------------------

    The EPA assessed other potential interpretations of the regulatory 
compliance exemption while developing the proposed approach. In 
particular, the EPA assessed an approach that would instead only exempt 
the emissions from individual CAA section 111(b) and (d) sources, 
rather than the emissions of the entire subpart W facility. For 
example, if certain pneumatic devices are regulated under NSPS OOOOb/EG 
OOOOc pursuant to CAA sections 111(b) and (d), all reported pneumatic 
device methane emissions from a subpart W facility would be subtracted 
from that facility's reported emissions. Under this approach, only 
emission sources at subpart W facilities that are not also CAA section 
111(b) and (d) facilities (e.g., methane slip from engines) would be 
considered when determining if a facility was above or below the waste 
emissions threshold. While this approach would exempt emissions 
associated with individual CAA section 111(b) and (d) facilities that 
are in compliance with the standards, as anticipated by the language in 
CAA section 136(f)(6)(A), the EPA does not believe that this approach 
would be consistent with the other text in that provision that is clear 
that the exemption applies to the ``applicable facility,'' which CAA 
section 136(d) defines as an entire subpart W facility. Further, we do 
not believe that it would be practical to implement the regulatory 
compliance exemption in this manner because the individual emissions 
source types in subpart W do not always align with the individual CAA 
section 111(b) and (d) facilities. Exempting methane emissions from 
individual subpart W source types that have a similar name as a CAA 
section 111(b) or (d) facility may exclude a broader or narrower scope 
of equipment or components and associated emissions than those subject 
to the NSPS OOOOb/EG OOOOc. Methane emissions from CAA section 111(b) 
or (d) facilities therefore cannot be directly subtracted from reported 
subpart W data.
    We request comment on the proposed approach for applying the 
regulatory compliance exemption to subpart W facilities and the 
proposed interpretation of the relevant statutory text. We also request 
comment on extending the regulatory compliance exemption to facilities 
in industry segments not currently covered by NSPS OOOOb/EG OOOOc 
requirements, in the event that such regulations pursuant to CAA 111(b) 
and (d) are finalized in the future. We recognize that the proposed 
approach to exempt entire subpart W facilities results in the

[[Page 5344]]

exemption of methane emissions from sources that are not subject to 
NSPS OOOOb/EG OOOOc. While we believe the proposed approach is the most 
consistent with the language in CAA section 136(f)(6), we request 
comment on alternative interpretations.
f. Determining Eligibility With Respect to CAA Section 136(f)(6)(A)
    It is expected that for many WEC applicable facilities, 
implementing NSPS OOOOb/EG OOOOc requirements would reduce methane 
emissions to levels below the waste emissions thresholds. The EPA 
interprets the regulatory compliance exemption as intending to provide 
relief from the WEC for WEC applicable facilities that remain above the 
waste emissions threshold even when their constituent CAA section 
111(b) and (d) facilities (i.e., emissions sources) are in full 
compliance with their applicable methane emissions requirements. This 
structure provides a further incentive for compliance with applicable 
requirements.
    The EPA proposes that the regulatory compliance exemption would 
only be available to WEC applicable facilities that exceed the waste 
emissions threshold. CAA section 136(f)(6)(A) states that ``charges 
shall not be imposed pursuant to subsection (c) on an applicable 
facility'' that meets the requirements of the regulatory compliance 
exemption. Subsection (c) in turn states that a charge shall be 
collected ``on methane emissions that exceed an applicable waste 
emissions threshold.'' Based on a plain reading of the statutory text, 
the EPA proposes that the exemption would not apply to WEC applicable 
facilities below the waste emissions threshold. Further, providing the 
exemption to WEC applicable facilities below the waste emissions 
threshold would serve no purpose as these facilities would not have 
positive WEC applicable emissions and therefore would not benefit from 
the exemption. Excluding facilities below the waste emissions threshold 
from the exemption would also reduce the reporting burden for those 
facilities, which would not be required to report information related 
to CAA section 111(b) and (d) compliance status.
    As discussed in this section, CAA section 136(f)(6)(A) does not 
specify the definition of compliance for the purposes of the exemption, 
and many different types of compliance deviations or violations can 
occur. The EPA is therefore proposing what actions constitute 
compliance with a methane emissions requirement, pursuant to CAA 
section 136(f)(A), for the purposes of implementing the regulatory 
compliance exemption. The EPA's proposed approach is intended to 
provide a clear threshold for establishing compliance status and 
eligibility for the exemption while minimizing the burden on industry 
and facilitating ease of implementation. The EPA is also proposing 
related reporting requirements for WEC applicable facilities that are 
necessary to implement the regulatory compliance exemption (see section 
II.D.2.g. of this preamble).
    CAA section 136(f)(6)(A) states that the WEC shall not be imposed 
``on an applicable facility that is subject to and in compliance with 
methane emissions requirements pursuant to subsections (b) and (d) of 
section 111.'' For the purpose of determining WEC facility eligibility 
for the regulatory compliance exemption, the EPA proposes that the 
compliance status of CAA section 111(b) and (d) facilities contained 
within a WEC applicable facility would be assessed based on compliance 
with the applicable methane emissions requirements for the Oil & 
Natural Gas Source Category (40 CFR part 60, subparts OOOOa, OOOOb, and 
OOOOc).
    Further, the EPA proposes that should additional NSPS/EG 
regulations for the oil and natural gas industry source category be 
finalized in the future, compliance with the methane emissions 
requirements in those regulations would be assessed for determining 
eligibility for the regulatory compliance exemption. As discussed in 
section II.D.2.h. of this preamble, the regulatory compliance exemption 
could become unavailable if future NSPS/EG revisions result in a 
situation such that those revisions, upon implementation, result in 
fewer emissions reductions than achieved by the NSPS OOOOb/EG OOOOc 
2021 Proposal, had that proposal been finalized and implemented. 
Similarly, the exemption could be reinstated upon adoption and 
implementation of NSPS/EG revisions that restore emissions reduction 
equivalency with, or improvement upon, the NSPS OOOOb/EG OOOOc 2021 
proposal. In such cases where a future NSPS/EG rule only applies to 
equipment in a segment of the oil and natural gas industry not covered 
by an existing NSPS/EG rule, the EPA proposes that any WEC applicable 
facilities with existing access to the regulatory compliance exemption 
would maintain that access. In other words, the ``all states'' 
requirement in CAA section 136(f)(6)(A)(i) would be assessed separately 
for the additional equipment covered by the new NSPS/EG, and any 
existing access to the exemption would not be lost while the 
determination is being made that CAA section 111(d) plans pursuant to 
the new EG rule were approved and in effect.
    The EPA requests comment on its proposed approach for how NSPS 
OOOOa, NSPS OOOOb, and EG OOOOc should be considered for the purposes 
of the regulatory compliance exemption. The EPA also requests comment 
on its proposed approach in light of any potential future NSPS/EG rules 
for the oil and natural gas industry source category, or any other 
additional source category that might cover emissions sources at a WEC 
affected facility, and the role of any such future methane emissions 
requirements in determining eligibility for the regulatory compliance 
exemption.
    The EPA proposes that any WEC applicable facility that contains CAA 
section 111(b) or (d) facilities would receive the regulatory 
compliance exemption if each of the CAA section 111(b) and (d) 
facilities that constitute the WEC applicable facility has no 
deviations or violations of the methane emissions requirements 
promulgated pursuant to the applicable NSPS or EG-implementing state 
and Federal plans. The EPA is proposing that this compliance 
requirement would apply for each CAA section 111(b) or (d) facility for 
each reporting year for the WEC applicable facility. For example, if 
all CAA section 111(b) or (d) facilities contained in a WEC applicable 
facility were in compliance with the applicable methane emissions 
requirements during a particular reporting year, the regulatory 
exemption would apply for that reporting year. If any CAA section 
111(b) or (d) facilities contained in a WEC applicable facility in the 
respective reporting year were not in compliance with emissions 
requirements, the regulatory exemption would not apply for that 
reporting year. The EPA proposes that if a WEC applicable facility were 
to lose access to the regulatory compliance exemption in a reporting 
year due to a deviation or violation in that reporting year, it would 
be able to receive the exemption in any subsequent reporting year if 
there were no deviations or violations in that applicable reporting 
year.
    The EPA is proposing that a WEC applicable facility would not be 
eligible for the regulatory compliance exemption if any CAA section 
111(b) or (d) facility that is contained within the WEC applicable 
facility has one or more deviations or one or more violations of any 
methane emissions requirement under the applicable NSPS or state or 
Federal plan issued pursuant to the EG.

[[Page 5345]]

The EPA recognizes that there are many potential elements to compliance 
with the methane requirements promulgated under CAA sections 111(b) and 
(d), such as compliance with a quantitative emissions limit and 
compliance with work practice standards, as well as multiple 
monitoring, recordkeeping, and reporting requirements. The EPA proposes 
to find that a deviation or violation from any of the methane 
requirements promulgated under CAA sections 111(b) and (d) constitutes 
non-compliance for purposes of the regulatory compliance exemption. The 
EPA believes that this approach is most consistent with the plain 
language of CAA section 136(f)(6)(A), which states that charges shall 
not be imposed on a facility that is ``subject to and in compliance 
with methane emissions requirements pursuant to subsections (b) and (d) 
of section 111.'' \38\ First, Congress made clear that it is not enough 
for a particular facility to be subject to methane regulations; each 
facility must also comply with those regulations. And in establishing 
what it means to comply, Congress did not employ any mitigating 
language. It is not enough to be ``substantively'' in compliance, for 
example, or ``in compliance with all major requirements''. Facilities 
must be ``in compliance with requirements'' pursuant to 111(b) and (d).
---------------------------------------------------------------------------

    \38\ 42 U.S.C. 7436(f)(6)(A).
---------------------------------------------------------------------------

    The EPA evaluated several alternative criteria for the regulatory 
compliance exemption eligibility. Another interpretation could be to 
apply a threshold, such as specific quantitative threshold 
requirements, for the regulatory compliance exemption. For example, the 
EPA might specify that a WEC applicable facility would still be deemed 
to be in compliance for purposes of the regulatory compliance exemption 
where the number of deviations or violations, or a quantity of excess 
emissions, fall below a specified threshold, as applied for all the CAA 
section 111(b) and (d) facilities contained in a WEC applicable 
facility. However, for the reasons discussed in the following 
paragraph, the EPA is not proposing this alternative.
    Deviations from or violations of any compliance requirements can 
vary significantly in severity and impact, as well as frequency. For 
example, a WEC applicable facility could contain many CAA section 
111(b) and (d) facilities with numerous deviations that, even 
collectively, result in a small amount of excess emissions. Another WEC 
applicable facility could contain a single CAA section 111(b) or (d) 
facility with a single deviation or violation that resulted in methane 
emissions significantly exceeding those that would have resulted had 
the CAA section 111(b) or (d) facility been in compliance with its 
methane emissions requirements. Violations of the emission standards 
are not the only violations that may be significant. Violations of 
monitoring requirements can be very serious, given that failure to do 
monitoring, or doing it incorrectly, can result in significant 
emissions not being discovered or corrected. Reporting violations can 
also be very serious, if they result in government being unaware of 
significant problems and thus unable to address them. For these and 
many other reasons, there is often no easy way to determine the 
seriousness of particular violations without fact specific and resource 
intensive investigation. Given that deviations from and violations of 
requirements for emission standards under CAA section 111(b) and of 
state or Federal plan requirements under CAA section 111(d) can vary in 
type, severity, and frequency, and given that CAA section 136(f)(A) 
does not further specify what constitutes compliance for the purpose of 
the regulatory compliance exemption, the EPA is not proposing a 
specific quantitative threshold requirement for the regulatory 
compliance exemption (e.g., number of violations or quantity of excess 
emissions).
    Because under the statute the availability of the regulatory 
compliance exemption requires two threshold findings, including that 
all plans are approved and in effect, the exemption would not be 
available until several years after finalization of the WEC rule. See 
the discussion in section II.D.2.b of this preamble regarding the 
proposed approach for timing of the regulatory compliance exemption 
availability. With the exception of several sources (e.g., combustion 
emissions for certain industry segments), most methane emission sources 
in covered industry segments required to report emissions under subpart 
W would also be subject to the CAA section 111(b) or (d) methane 
requirements promulgated in the final NSPS OOOOb and the plans issued 
and approved under EG OOOOc. The EPA expects that, as oil and gas 
operations implement the requirements of final NSPS OOOOb and the plans 
issued and approved pursuant to EG OOOOc (and undertake other methane 
mitigation voluntarily or due to other Federal or state regulations), 
total reported subpart W facility methane emissions would decline.
    For many WEC applicable facilities, if the CAA section 111(b) and 
(d) facilities contained within a WEC applicable facility are in 
compliance with methane requirements promulgated under CAA sections 
111(b) and (d), the WEC applicable facility would likely be below the 
waste emissions threshold. The Agency therefore expects that even if 
CAA section 111(b) or (d) facilities within these WEC applicable 
facility have compliance deviations, these WEC applicable facilities 
will likely remain below the waste emissions thresholds. In the 
alternative, the EPA expects that cases of significant or widespread 
compliance deviations or violations with the requirements promulgated 
under CAA section 111(b) or (d) could result in emission levels for a 
WEC applicable facility that could exceed the waste emissions 
thresholds. Because many WEC applicable facilities are expected to be 
below the waste emissions threshold when the regulatory compliance 
exemption becomes available, the EPA expects that deviations or 
violations will not have a significant impact for these facilities--
they would not be eligible for the exemption not only because they are 
out of compliance, but also because they are below the waste emissions 
threshold, and there is no charge to exempt in that case.
    The EPA requests comment on the proposed provisions for determining 
``compliance'' for the purposes of the regulatory compliance exemption 
and the alternative approaches the agency considered. The EPA requests 
comment on specific criteria (e.g., types of deviations or violations, 
quantitative thresholds) that could be applied to determine compliance 
with methane emissions requirements promulgated under CAA sections 
111(b) and (d) for the purpose of assessing WEC applicable facility 
eligibility for the regulatory compliance exemption. The EPA requests 
comment on whether the criteria should consider whether the deviation 
or violation resulted in excess emissions, as demonstrated by 
monitoring and other data. The EPA also requests comment on excluding 
WEC applicable facilities below the waste emissions threshold from the 
regulatory compliance exemption.
g. Reporting and Recordkeeping Requirements for the Regulatory 
Compliance Exemption
    We are proposing a reporting requirement at 40 CFR 99.7(b)(2)(iv) 
that would require that once the Administrator has made a determination 
that the requirements in CAA section 136(f)(6)(A) have been met, 
information

[[Page 5346]]

related to the regulatory compliance exemption must be included in the 
WEC filing submitted by the WEC obligated party for each WEC applicable 
facility exceeding the waste emissions threshold that contains any CAA 
section 111(b) and (d) affected facilities. CAA section 136(f)(6)(A) 
mandates that the EPA shall not impose a charge upon WEC applicable 
facilities that qualify for the regulatory compliance exemption. The 
proposed approach for implementing the regulatory compliance exemption 
would make facilities that are below the waste emissions threshold 
ineligible for the exemption. The EPA therefore proposes that WEC 
obligated parties would not be required to report information related 
to the compliance status of CAA section 111(b) and (d) facilities 
contained within WEC applicable facilities for WEC applicable 
facilities that are below the waste emissions threshold.
    The reporting requirements for facilities with the regulatory 
compliance exemption are proposed at 40 CFR 99.42. We are proposing 
that the filing would include a representation of the NSPS and state 
and Federal plan compliance status for each CAA section 111(b) and (d) 
facility located within a WEC applicable facility during the reporting 
year. This representation of compliance status would indicate whether 
the facility was in full compliance for the entirety of the reporting 
year (i.e., for each CAA section 111(b) and (d) facility, there were no 
violations or deviations), or whether there were one or more deviations 
or violations during the reporting year. For facilities that meet all 
eligibility requirements for the exemption, we are proposing to require 
reporting of the ICIS-AIR ID (or if unavailable, the facility registry 
service (FRS) ID and EPA Registry ID from CEDRI) reporting identifiers 
for each CAA section 111(b) and (d) facility located at the WEC 
applicable facility. These identifiers are information necessary for 
the EPA to assess the accuracy of the representation of compliance 
status through linkages to reports and emissions and compliance data 
for each CAA section 111(b) and (d) facility located at the WEC 
applicable facility.
    As supporting documentation for the representation of compliance 
status of WEC applicable facilities that are eligible for the exemption 
but were not in full compliance for the entirety of the reporting year, 
we are proposing to require the submittal of one report associated with 
the CAA section 111(b) and (d) facilities located within the WEC 
applicable facility that documents a deviation or violation during the 
reporting year. As supporting documentation for the representation of 
compliance status of WEC applicable facilities that are eligible for 
the exemption and that were in full compliance for the entirety of the 
reporting year, we are proposing to require the submittal of report(s) 
associated with the CAA section 111(b) and (d) facilities located 
within the WEC applicable facility. The EPA recognizes that the 
compliance certification period for CAA section 111(b) and (d) 
facilities may not align with the reporting year for which the filing 
is being completed and that at the time of the WEC filing due on March 
31 of each year, report(s) covering the complete preceding reporting 
year for WEC filing may not be available. To accommodate for these 
cases where a report is not available for the complete reporting year 
of WEC filing, the EPA is proposing that the WEC obligated party would 
provide the report, if available, that covers a portion of the year, 
identify the period of time covered by the report, and for the 
remainder of the year provide a representation of compliance status for 
each CAA section 111(b) and (d) facility at the WEC applicable facility 
that is not included in the submitted report. It also is possible that 
the complete calendar year of WEC filing is covered by two annual 
reports, each covering a portion of the calendar year. In this case, 
the WEC applicable facility should submit both annual reports. The EPA 
further recognizes that a WEC applicable facility may contain CAA 
section 111(b) and (d) facilities that first became subject to 
requirements under CAA sections 111(b) and (d) during the reporting 
year associated with the filing and for which the first year of 
compliance is not completed. For these CAA section 111(b) and (d) 
facilities, we are proposing to require that the filing identify the 
type of facility, that date that it became subject, and a 
representation of the compliance status for the portion of the year in 
which it was subject to requirements under CAA sections 111(b) and (d). 
In cases where the initial filing does not include a report covering 
the entire reporting year, we are proposing to require that the WEC 
obligated party provide a revised filing once such a report becomes 
available. The EPA is proposing that this revised filing under the WEC 
rule would be required to be made on or before the date that the 
compliance report covering the remainder of the year would be due under 
the applicable requirements of CAA section 111(b) or (d). The deadlines 
for filing revisions to WEC filings as discussed in section III.A.4. do 
not apply for the submittal of compliance reports.
    The EPA requires this information for the verification of exemption 
eligibility. Reported information will be used to conduct verification 
as discussed in section III.A.4., and reported information, records and 
other information as applicable will be used to conduct any auditing 
that occurs under section III.E.1.
    The EPA is aware that this proposed reporting program may result in 
cases where a WEC obligated party makes a good-faith representation 
that each CAA section 111(b) and (d) facility at the WEC applicable 
facility is in compliance but later independently discovers the 
existence of one or more deviations or violations. In this proposed 
rulemaking, such independent discoveries would be considered to be 
substantive errors within the WEC filing. Proposed 40 CFR 99.7(e)(1) 
would require submittal of a revised WEC filing within 45 days of the 
discovery that a previously submitted WEC filing contains a substantive 
error. Provided that timely submittal of a revised filing is made, if a 
revised regulatory compliance exemption filing results in the 
imposition of WEC obligation from a WEC applicable facility that 
previously qualified for exemption, we are proposing that the WEC 
obligated party would not be subject to interest penalties normally 
assessed for payments made after March 31, as discussed in section 
III.B.1. of this preamble.
    However, later discoveries of deviations or violations by the EPA 
or another regulatory authority, or discoveries as a result of 
investigation by the EPA or another regulatory authority (including 
information requests), are not treated the same way as errors. Where a 
WEC obligated party represents that each CAA section 111(b) and (d) 
facility at the WEC applicable facility is in compliance, but the EPA 
or another regulatory authority subsequently discovers the existence of 
one or more deviations or violations, or the CAA section 111(b) and (d) 
facility identifies the deviation or violation as a result of an EPA 
investigation (including information requests), the WEC obligated party 
may be subject to enforcement and required to pay any outstanding WEC 
fees and interest penalties. False statements may be subject to 
criminal enforcement.
    The EPA seeks comment on the reporting and recordkeeping 
requirements for the regulatory compliance exemption. We seek

[[Page 5347]]

comment on whether additional information should be collected or 
retained to allow for verification of eligibility for the exemption.
h. Resumption of WEC Under CAA Section 136(f)(6)(B)
    CAA section 136(f)(6)(B) states that if, at any point after the 
Administrator has made the determination required by CAA section 
136(f)(6)(A), the conditions for such determination are no longer met, 
the regulatory compliance exemption ceases to apply. Because the EPA 
proposes to determine that the regulatory compliance exemption is only 
available if all states are subject to standards and plans pursuant to 
CAA sections 111(b) and (d) that are, collectively, equivalent to the 
NSPS OOOOb/EG OOOOc 2021 Proposal, the EPA proposes that all WEC 
applicable facilities would lose access to the exemption if either of 
the conditions in CAA section 136(f)(6)(A) ceased to apply. For 
example, if a state plan were legally challenged and vacated after the 
initial determination, plans would no longer be approved and in effect 
in all states, and the regulatory compliance exemption would no longer 
be available. Similarly, if after the initial equivalency determination 
methane emissions requirements promulgated under CAA section 111(b) or 
(d) were modified such that they no longer resulted in equivalent or 
greater aggregate emissions reductions than the NSPS OOOOb/EG OOOOc 
2021 Proposal, the exemption would no longer be available. Note that in 
addition to future revisions to EG, revisions to the requirements in 
individual state plans pursuant to CAA section 111(d) could also result 
in a situation in which implementation of the final NSPS and state or 
federal plans does not achieve equivalent or greater emissions 
reductions compared to the 2021 NSPS OOOOb/EG OOOOc Proposal. (The 
conditions under which an individual WEC applicable facility would 
receive or become ineligible for the regulatory compliance exemption 
while the conditions in CAA section 136(f)(6)(A) are still met are 
discussed in section II.D.2.f. of this preamble.) The EPA proposes that 
any determination that the criteria in CAA section 136(f)(6)(A) are no 
longer met after the initial determination would be made through a 
future administrative action. The EPA proposes that access to the 
exemption would be lost for the full calendar year in which the 
required criteria were no longer met. The EPA proposes that if access 
to the regulatory compliance exemption were lost after it was initially 
made available because one of the two required conditions in CAA 
section 136(f)(6)(A) were no longer met, it could become available 
again following a subsequent determination that both conditions were 
once again achieved. Under such circumstances, the exemption would 
become available again for the reporting year in which the conditions 
were met. The EPA proposes that if the conditions ceased to apply and 
were then met again in the same reporting year, the exemption would be 
available for the entire reporting year. The EPA requests comment on 
alternative approaches that would revoke the regulatory compliance 
exemption for a portion of the year in which the requirements were no 
longer met and how data under such an approach could be pro-rated for 
the purposes of determining WEC. The EPA requests comment on the 
proposed implementation of CAA section 136(f)(6)(B). While the EPA 
believes the proposed implementation of CAA section 136(f)(6)(B) is 
consistent with a plain reading of the statutory text and consistent 
with the proposed timing of the regulatory compliance determinations 
under CAA section 136(f)(6)(A) (i.e., methane emissions standards and 
plans pursuant to subsections (b) and (d) of section 111 have been 
approved and are in effect in all States), the agency requests comment 
on an approach in which access to the exemption would be lost at a 
state-by-state level. In this alternative approach, if circumstances 
occurred such that a state plan was no longer approved and in effect, 
only the WEC applicable facilities located in that state would lose 
access to the exemption; for WEC applicable facilities that span 
multiple states, access would be lost if the state plan for any of the 
states in which the WEC applicable facility is located were no longer 
approved and in effect.
3. Plugged Well Exemption Under CAA Section 136(f)(7)
    Plugged wells have lower methane emissions than active wells and 
unplugged inactive wells; therefore, plugging wells will reduce total 
facility emissions potentially subject to WEC. Congress created an 
incentive for plugging and permanently shutting wells by including an 
exemption from the WEC in CAA section 136(f)(7): ``[c]harges shall not 
be imposed with respect to the emissions rate from any well that has 
been permanently shut-in and plugged in the previous year in accordance 
with all applicable closure requirements, as determined by the 
Administrator.''. Separately, in CAA section 136(a)(3)(D) and 136(b), 
Congress provided funding that can assist owners and operators who 
elect to voluntarily and permanently shut in and plug wells on non-
Federal land.\39\
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    \39\ On August 30, 2023, the EPA, U.S. Department of Energy, and 
National Energy Technology Laboratory announced the availability of 
up to $350 million in formula grant funding to eligible states to 
help monitor and reduce methane emissions from marginal conventional 
wells, including to help owners and operators voluntarily and 
permanently reduce methane emissions from marginal conventional 
wells. Inflation Reduction Act (IRA)--Mitigating Emissions from 
Marginal Conventional Wells, Funding Opportunity Number DE-FOA-
003109, available at: https://www.grants.gov/web/grants/view-opportunity.html?oppId=350045.
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    In this rule, we are proposing that this exemption would be 
applicable to wells in the onshore and offshore petroleum and natural 
gas production industry segments. We interpret this exemption to apply 
to the production industry segments only and not to wells in other 
segments, such as storage wells. Production wells are distinctly 
different in purpose and emissions profile than underground storage 
wells, which are generally replaced with new storage wells then they 
are plugged and abandoned. We seek comment on including wells in the 
underground natural gas storage industry segment under this exemption. 
We are proposing that in the WEC filing, exempted emissions would be 
those from wells permanently shut-in and plugged in the previous year 
(i.e., if a well is permanently shut-in and plugged in 2026, the 
exempted emissions would be deducted from the 2026 emissions totals 
that are filed under WEC in 2027).
a. Determining if the Exemption for Permanently Shut-In and Plugged 
Wells Applies to a WEC Applicable Facility
    The EPA is proposing two criteria for determining if the exemption 
for permanently shut-in and plugged wells applies to a WEC applicable 
facility.
    Consistent with the other exemptions, the first criterion is that 
the facility must have emissions that exceed the waste emissions 
threshold. CAA 136(c)(7) notes that ``charges shall not be imposed'' on 
emissions from permanently shut-in and plugged wells. Charges would not 
be imposed on emissions below the threshold and therefore an exemption 
is unnecessary in cases where facility emissions are below the 
threshold. The EPA proposes that emissions from facilities that are 
below the waste emissions threshold would not be exempted. The EPA 
proposes that for facilities that exceed the waste emissions threshold, 
emissions eligible for the plugged well exemption could be subtracted 
up to the point where facility emissions equal the waste emissions 
threshold (i.e., the

[[Page 5348]]

lowest possible WEC applicable emissions for a facility with the 
plugged well exemption would be zero).
    Second, wells must meet the following definition of permanently 
shut-in and plugged in accordance with all applicable closure 
requirements. The EPA proposes that for the purposes of this exemption, 
a permanently shut-in and plugged well is one that has been permanently 
sealed to prevent any potential future leakage of oil, gas, or 
formation water into shallow sources of potable water, onto the 
surface, or into the atmosphere. For the purposes of this exemption, 
the EPA is proposing that a well would be considered to be permanently 
shut-in and plugged, in accordance with all applicable closure 
requirements, if the owner or operator has met all applicable Federal, 
state, and local requirements for closure in the jurisdiction where the 
well is located. For the purposes of this exemption, we are proposing 
that a well would be considered permanently shut-in and plugged on the 
date a metal plate or cap has been welded or cemented onto the casing 
end.
    Section II.D.3.c. below details the reporting requirements for this 
exemption which provide information necessary for verification of the 
exemption eligibility and exempted emission quantities.
    In addition to requirements specifying how to plug a well, relevant 
Federal, state, and local requirements often also specify requirements 
such as for notifications, reporting, and site remediation. For 
purposes of 40 CFR part 99, we propose that the applicable closure 
requirements would include only the requirements specific to well 
plugging. We are not proposing to include requirements for 
notifications, reporting, and site remediation as part of the exemption 
eligibility criteria for following ``all applicable closure 
requirements'' because the closure of the well is the key activity 
impacting methane emissions, which is the focus of the WEC, and these 
other aspects of closure are less relevant to methane emissions levels. 
We also note that had we proposed to include these additional 
requirements in our interpretation of ``all applicable closure 
requirements,'' the reporting requirements would increase for 
permanently shut-in and plugged wells and this may lead to 
recalculations of WEC years after the exemption was initially applied. 
We request comment on whether ``all applicable closure requirements'' 
should instead be interpreted to include notifications, reporting, site 
remediation and other post-closure activities at plugged well.
b. Calculations of Exempted Emissions From Permanently Shut-In and 
Plugged Wells
    The EPA proposes that the methane emissions eligible for the 
exemption are those that occur at the well level including those from 
wellhead equipment leaks, liquids unloading, and workovers with and 
without hydraulic fracturing in the reporting year in which the well 
was plugged. We are proposing to only consider these emissions sources 
in the calculation of exempted emissions for the permanently shut-in 
and plugged well as we expect use of production-related equipment or 
equipment associated with treating production streams generally (e.g., 
AGRU, dehydrator, separator) to be at a minimum. We are proposing to 
limit the emissions quantity to the source types we expect to represent 
the most significant emissions share expected at permanently shut-in 
and plugged wells. We note that methane emissions in the reporting year 
from other equipment onsite (e.g., separator, compressor, flare) may 
result from multiple wells and not just the wells that are plugged in 
the reporting year. We request comment on an interpretation that would 
exempt all methane emissions associated with the production from the 
permanently shut-in and plugged well--not limited to the wellhead 
equipment leaks, liquids unloading, and workovers as is included in 
this proposal--during the calendar year of closure, including the 
methodology by which methane emissions from non-wellhead specific 
sources in subpart W could be attributed to the permanently shut-in and 
plugged well.
    For the purposes of quantifying the methane emissions from 
equipment leaks, liquids unloading, workovers with hydraulic 
fracturing, and workovers without hydraulic fracturing associated with 
each permanently shut-in and plugged well, we are proposing to use the 
methane emissions and throughput data collected or reported to subpart 
W of part 98. As discussed previously in this preamble, proposed 
amendments in the 2023 Subpart W Proposal impact the data available to 
best estimate the exempted emissions from the permanently shut-in and 
plugged well. Therefore, as described in more detail in this section, 
for applicable emission sources and industry segments, different 
approaches are proposed for certain time periods.
    The current subpart W rule requires that onshore petroleum and 
natural gas production facilities report methane emissions from liquids 
unloading and workovers to be reported by sub-basin for each WEC 
applicable facility as well as methane emissions from equipment leaks 
at the facility-level. Subpart W of part 98 also currently requires 
offshore petroleum and natural gas production facilities and onshore 
petroleum and natural gas production facilities to report facility-
level throughput of gas and oil handled or sent to sale, respectively. 
Proposed revisions included in the 2023 Subpart W Proposal would 
require onshore petroleum and natural gas production facilities to 
report additional elements that facilitate quantification of methane 
emissions from individual shut-in and plugged wells. Specifically, 
beginning in reporting year 2024, the 2023 Subpart W Proposal would 
require onshore petroleum and natural gas production facilities to 
report well-level throughput volumes for gas and oil sent to sale from 
wells that are permanently shut-in and plugged. Additionally, beginning 
in reporting year 2025, the 2023 Subpart W Proposal would increase the 
granularity of methane emissions reporting for liquids unloading and 
workovers to the well-level and methane emissions reporting for 
equipment leaks to the well pad level. Due to the differences in 
available reporting data for 2024 and future years, the proposed 
approach for quantifying methane emissions in part 99 for individual 
wells located at onshore petroleum and natural gas production 
facilities that are permanently shut-in and plugged in 2024 would be 
different than the proposed approach for quantifying methane emissions 
from wells located at onshore petroleum and natural gas production 
facilities that are permanently shut-in and plugged in 2025 and future 
years.
    For reporting year 2024, the EPA proposes through 40 CFR 99.52 that 
WEC applicable facilities in the onshore petroleum and natural gas 
industry segment would quantify methane emissions from permanently 
shut-in and plugged wells by allocating the subpart W of part 98 
reported facility-level equipment leak, liquids unloading, and workover 
methane emissions using subpart W of part 98 reported production 
volumes of gas and oil sent to sale. We are proposing that WEC 
applicable facilities in the onshore petroleum and natural gas industry 
segment would sum the total subpart W of part 98 reported methane 
emissions from equipment leaks, liquids unloading, and workovers, and 
multiply the sum of the methane emissions by the ratio of subpart W of 
part 98 reported production at the permanently shut-in and plugged well 
to the subpart

[[Page 5349]]

W of part 98 reported facility-level total production.
    For facilities with only gas production with exempt plugged well 
emissions, we are proposing that the reported gas produced from the 
plugged wells be divided by the total gas production at the facility to 
develop the ratio. For facilities with only oil production with exempt 
plugged well emissions, we are proposing that the reported oil produced 
from the plugged wells be divided by the total oil production at the 
facility to develop the ratio. For facilities with both gas and oil 
production with exempt plugged well emissions, we are proposing that 
gas production that is reported to subpart W of part 98 by the WEC 
applicable facility in the onshore petroleum and natural gas industry 
segment would be converted to barrels of oil equivalent using a default 
value of 6,000 scf/barrel, such that throughput volumes will be on the 
same basis for facilities that report production of gas and oil. We are 
seeking comment on whether the EPA should provide an option for WEC 
applicable facilities to use a facility-specific value for barrels of 
oil equivalent, including whether facilities routinely determine this 
value and whether significant variability is expected in this value.
    For 2025 and future years, we are proposing that WEC applicable 
facilities in the onshore petroleum and natural gas industry segment 
would estimate well-level emissions in accordance with part 98 methods 
for the permanently shut-in and plugged well. As described previously, 
for 2025 and future years, subpart W of part 98 would require reporting 
of methane emissions from liquids unloading and workovers to be at the 
well-level for facilities in the onshore petroleum and natural gas 
industry segment, therefore we are proposing that facilities in the 
onshore petroleum and natural gas industry segment would utilize the 
methane emissions as -reported to subpart W part 98 in their part 99 
exemption calculation for these emissions sources. Also, as described 
previously, for 2025 and future years, subpart W of part 98 would 
require reporting of methane emissions from equipment leaks at the well 
pad for facilities in the onshore petroleum and natural gas industry 
segment. In order to obtain a well-level estimate for the part 99 
exemption calculation, we are proposing to require facilities in the 
onshore petroleum and natural gas industry segment to utilize the 
subpart W of part 98 input data and emission estimation methods for 
wellhead equipment leaks to calculate the methane emissions at the well 
level for the permanently shut-in and plugged well. For example, if the 
equipment leak methane emissions at the well pad that includes the 
permanently shut-in and plugged well were estimated using the leaker 
method in 40 CFR 98.233(q), the WEC applicable facility would use the 
count of leakers by component type (e.g., valve, connector) recorded 
for the permanently shut-in and plugged well, the operating time of the 
well during the year, and the appropriate emissions factors from 
subpart W of part 98 to estimate the methane emissions from the 
permanently shut-in and plugged well. Similarly, if the equipment leak 
methane emissions at the well pad that includes the permanently shut-in 
and plugged well were estimated using the population count method in 40 
CFR 98.233(q), the WEC applicable facility would use the operating time 
of the well during the year and the appropriate emissions factors from 
subpart W of part 98 to estimate the emissions from the permanently 
shut-in and plugged well.
    For offshore petroleum and natural gas production facilities, the 
current subpart W of part 98 reporting requirements are based on the 
facility's submission to the Bureau of Ocean Energy Management (BOEM), 
which includes methane emissions for component-level equipment leaks. 
The methane emissions required to be reported by offshore facilities 
would be unchanged by the 2023 Subpart W Proposal as it pertains to 
this exemption in that these facilities will continue to report the 
data from their BOEM report. Subpart W of part 98 also currently 
requires offshore petroleum and natural gas production facilities to 
report facility-level throughput of gas and oil handled in the 
reporting year. Proposed revisions included in the 2023 Subpart W 
Proposal for offshore petroleum and natural gas production facilities 
would add requirements for the reporting of well-level throughput 
volumes for gas and oil sent to sale from wells that are permanently 
shut-in and plugged beginning in reporting year 2024. The 2023 Subpart 
W Proposal would also revise the terms in the current reporting 
elements for facility-level throughputs to refer to gas sent to sale, 
rather than handled, for consistency with the CAA language and with the 
onshore production industry segment. As noted in the preamble for the 
2023 Subpart W Proposal, these verbiage changes for facility-level 
throughput are not expected to impact the quantity of production 
volumes reported and were made for consistency and clarity. For the 
purposes of estimating the exempted emissions for permanently shut-in 
and plugged wells at offshore petroleum and natural gas production 
facilities, we are proposing that facilities allocate the component 
level equipment leaks (i.e., those from valves, connectors) reported to 
subpart W of part 98 by the ratio of production from the well that has 
been permanently shut-in and plugged to the total facility-level 
production. Analogous to the approach for onshore petroleum and natural 
gas production facilities for reporting year 2024, we are proposing 
that gas sent to sale be converted to BOE using a default value of 
6,000 scf/bbl BOE.
    For all reporting years and applicable industry segments, if the 
WEC applicable facility has more than one permanently shut-in and 
plugged well, we are proposing that the part 99 emissions calculations 
would be performed for each well and summed to determine the net annual 
quantity of methane emissions at the WEC applicable facility eligible 
for the exemption.
c. Reporting and Recordkeeping Requirements for the Exemption for 
Permanently Shut-In and Plugged Wells
    Through the provisions proposed at 40 CFR 99.51, the EPA is 
proposing that the WEC obligated party receiving the exemption would 
provide for each well at a WEC applicable facility, the well ID number 
as reported to subpart W of part 98; the date the well was permanently 
shut-in and plugged; the statutory citation for each state, local, and 
Federal regulation stipulating requirements that were applicable to the 
closure of the permanently shut-in and plugged well; the emission 
attributable to the well, and for each WEC applicable facility, the 
total emissions attributable to all permanently shut-in and plugged 
wells at the facility; and a certification statement by the designated 
representative for the WEC obligated party that all identified wells 
were closed in accordance with state, local, and Federal requirements. 
We are proposing that the information included in the report would be 
subject to the general recordkeeping requirements for part 99, meaning 
these records must be retained for 5 years following the WEC filing 
year of the exemption such that they can be made available to the EPA 
for inspection and review.
    The EPA requires this information for the verification of exemption 
eligibility and of exempted emission quantity. Reported information 
will be used to conduct verification as discussed in section III.A.4., 
and reported information, records and other information as applicable 
will be used

[[Page 5350]]

to conduct any auditing that occurs under section III.E.1.
    The EPA seeks comment on the reporting and recordkeeping 
requirements for the exemption for emissions from wells that are 
permanently shut-in and plugged. We seek comment on whether additional 
information should be collected or retained to allow for verification 
of the quantity of emissions eligible for the exemption.

III. General Requirements of the Proposed Rule

A. WEC Reporting Requirements

1. Required Reporters
    The WEC obligated party would be required to submit a WEC filing 
annually by March 31 that would include data collected from each WEC 
applicable facility of which it (the WEC obligated party) is comprised 
as of December 31 of each reporting year. The WEC filing would provide 
the data necessary for the EPA to assess and verify the WEC obligation 
including certain part 98 emissions information and netting, as 
applicable, as well as supporting documentation for any WEC applicable 
facility exemptions.
2. Reporting Deadlines
    As required under the CAA sections 136(c) and (e), the assessment 
of the first WEC will be based on data collected under subpart W of the 
GHGRP beginning on January 1, 2024. We are proposing in 40 CFR 99.5 
that the first WEC filing would be due March 31, 2025, and would be 
required to be submitted annually by March 31 thereafter, as 
applicable. We have proposed the March 31 reporting deadline under this 
action for the purpose of quantifying WEC such that the information 
reported for part 99 can be done in coordination with and on the same 
schedule as (i.e., by March 31 of the calendar year following the 
reporting year) the information reported under subpart W.
    The EPA is proposing that final revisions to the first WEC filing, 
with the exception of resubmissions to provide CAA section 111(b) or 
(d) compliance reports or revisions to previously reportd compliance 
reports for the purposes of the regulaltory compliance exemption, would 
be due by November 1, 2025, and would be required to be submitted 
annually by November 1 thereafter, as applicable (see section III.A.4. 
of this preamble for discussion and request for comment on this 
deadline).
3. Submission of the WEC Filing
    The EPA proposes that each WEC filing must be submitted 
electronically in accordance with the requirements of 40 CFR 99.6 and 
in a format specified by the Administrator.
    As noted previously in this section of the preamble, the EPA 
proposes that each WEC obligated party will submit a WEC filing 
annually. The WEC filing content we are proposing is expected to 
provide the data necessary to complete the WEC calculations as 
described previously in the preamble. We are proposing WEC filing 
reporting requirements to cover general company information including 
physical address, email, telephone number, list of associated WEC 
applicable facilities and their identifying information (e.g., part 98, 
subpart W e-GGRT ID), as well as the net WEC emissions calculated in 
accordance with 40 CFR 99.22 and the WEC obligation as calculated 
pursuant to 40 CFR 99.23. We are also proposing that each WEC obligated 
party's WEC filing include certain information at the WEC applicable 
facility level. Specifically, we are proposing that for each WEC 
applicable facility that comprises the WEC obligated party, the 
reporting requirements would cover facility-level information including 
the facility's eGGRT ID, the facility's industry segment(s), the 
facility's waste emissions threshold calculated in accordance with 40 
CFR 99.20, and the facility's WEC applicable emissions calculated in 
accordance with 40 CFR 99.21.
    The EPA seeks comment on these reporting and recordkeeping 
requirements (e.g., date of WEC filing and payment for the first year). 
We seek comment on whether additional information should be reported to 
EPA or retained by the WEC obligated party or WEC applicable facility 
to allow for verification of the WEC filing.
    The EPA is also proposing reporting requirements for each WEC 
obligated party related to the three WEC exemptions, which are 
discussed in sections II.D.1. through 3. of this preamble. Under the 
proposed approach, the exemptions are only available to WEC applicable 
facilities that exceed the waste emissions threshold. The EPA therefore 
proposes that these reporting requirements would only apply to WEC 
applicable facilities that exceed the waste emissions threshold and are 
otherwise eligible for the exemption(s). The EPA seeks comment on the 
reporting requirements for each exemption, as noted in sections II.D.1. 
through 3. of this preamble.
4. Verification and WEC Filing Revisions
    We anticipate that the foundation of the WEC obligated party's WEC 
filing would be the methane emissions and throughput reported by the 
WEC applicable facilities in their subpart W reports. As specified in 
Sec.  98.3(f) and (h) of this chapter, part 98 currently includes a 
verification process and resubmission process for resolving substantive 
error(s) \40\ in reporting. These errors are either found through self-
discovery by the WEC obligated party or are found by the EPA during the 
verification process. In part 98, errors must be resolved within 45-
days from discovery or notification of the error by the EPA. The EPA 
may grant a 30-day extension request if the request is timely, such 
that a total of 75 days may be provided for complete issue resolution. 
Additional extensions may be approved by the Administrator in specified 
limited circumstances. Resolution is either made by report revision and 
resubmission or by providing an adequate demonstration that the 
previously submitted report does not contain the identified substantive 
error or that the identified error is not a substantive error. Upon 
satisfying these requirements, the EPA designates the part 98 report as 
verified. If the requirements in Sec.  98.3 of this chapter are not 
satisfied, the EPA considers the part 98 report unverified.
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    \40\ 40 CFR 98.3(h)(3): A substantive error is an error that 
impacts the quantity of GHG emissions reported or otherwise prevents 
the reported data from being validated or verified.
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    We are proposing that the verification status of the WEC applicable 
facility with respect to the reporting in subpart W part 98 would be 
considered by the EPA when determining the verification status of the 
part 99 filing because the subpart W data would be the cornerstone of 
the WEC. In effect, a WEC filing may not achieve verified status until 
all errors associated subpart W reports that impact total WEC are 
corrected. For example, if the subpart W part 98 report of one WEC 
applicable facility contains errors related to reported emissions or 
throughput that affect total WEC, the EPA could by extension consider 
the WEC filing of the WEC obligated party that includes that WEC 
applicable facility to be unverified. However, there may also be 
situations in which an unverified subpart W part 98 report does not 
impact the ability to accurately calculate a WEC obligated party's WEC 
obligation. In these circumstances, the proposed approach would allow 
the EPA to verify a WEC obligated party's part 99 report even if

[[Page 5351]]

the part 98 report of a WEC applicable facility associated with the WEC 
obligated party remained unverified.
    Separately, there are elements of the part 99 filing that would not 
be tied to the subpart W report, such as the calculation of the WEC 
including netting and any exemption information. We are proposing to 
implement a similar verification procedure under part 99 to that which 
exists under part 98. In implementing the verification of information 
submitted under part 99, the EPA envisions a two-step process. First, 
we propose to conduct an initial centralized review of the data that 
would help assure the completeness and accuracy of data. Second, the 
EPA intends to notify WEC obligated parties of potential errors, 
discrepancies, or make inquiries as needed concerning the WEC filing. 
Specifically for this rulemaking, we anticipate that there could be 
errors or clarifications with respect to the supporting documentation 
and quantification of emissions associated with exemptions from the 
WEC, which may require EPA review to evaluate and confirm their 
validity and accuracy. The part 99 verification review would identify 
issues resulting from the calculation of WEC based on verified subpart 
W GHGRP reports and verified WEC filings to the extent possible. A 
thorough discussion of the separate process for unverified reports and 
approach for reassessment of WEC obligation due to resubmissions is 
discussed in section III.B. of this preamble.
    We are proposing provisions that would require a WEC obligated 
party to resubmit their WEC filing within 45-days of either being 
contacted in writing by the EPA notifying them of the presence of a 
substantive error in their WEC filing or by self-discovering that a 
previously submitted WEC filing contains one or more substantive errors 
(except as described later in this section), or within 75 days if 
granted a 30-day extension per 40 CFR 99.7(e)(4). For the purposes of 
part 99, we are proposing to consider a substantive error to be an 
error that impacts the Administrator's ability to accurately calculate 
the WEC obligated party's obligation, which may include, but would not 
be not limited to, the list of WEC applicable facilities associated 
with a WEC obligated party and corresponding data reported in each 
listed WEC applicable facility part 98 report(s), emissions associated 
with exemptions, and supporting information for each exemption to 
demonstrate its validity. We are proposing that the revised WEC filing 
must correct all substantive errors or provide information 
demonstrating that the previously submitted report does not contain the 
identified substantive error or that the identified error is not a 
substantive error.
    We are also proposing that if a WEC applicable facility revises and 
resubmits their part 98 report, which results in impacts on the WEC 
calculations, the WEC obligated party would also be required to submit 
a revised WEC filing that includes the number of corrections and 
information detailing the correction(s) made. In the event that a 
subpart W report revision results in a change in the applicability of 
part 99 to the facility, under the proposed provisions the WEC 
obligated party would either submit a WEC filing adding or removing any 
facilities, as appropriate. As described in the paragraph below, with 
the exception of resubmissions to provide CAA section 111(b) or (d) 
compliance reports or revisions to previously reported compliance 
reports for the purposes of the regulatory compliance exemption, the 
EPA is proposing that part 99 resubmissions would only be allowed up to 
November 1 of the year following the reporting year. Any part 98 
resubmissions after this date that impact WEC calculations would not be 
required to be resubmitted in a revised WEC filing; facilities could 
continue to resubmit data under subpart W at any time. Resubmissions 
related to CAA section 111(b) or (d) compliance reports for the 
purposes of the regulatory compliance exemption must be made as 
discussed in section II.D.2.g. of this preamble. Under subpart W, 
facilities may resubmit data for historic reporting years via e-GGRT 
for the most recent five reporting years (e.g., submit updates to 2019 
data in 2022). Data resubmission for historic reporting years in the 
context of the WEC program is extremely complicated due to the 
potential changes in facility ownership over time and the implications 
this has on netting of emissions from facilities under common ownership 
or control. For example, a company or a facility owned by a company in 
one year may be owned in whole or in part by one or multiple different 
companies the next year. With such changes occurring annually to 
multiple facilities across multiple owners and operators with more than 
one facility under common ownership or control, there is no practical 
means of incorporating resubmitted data for historic reporting years in 
the WEC program. This would require the EPA to engage in a potentially 
constant series of WEC recalculations and associated invoicing or 
refunds. The EPA therefore proposes a deadline of November 1 for each 
year, after which time no WEC filings could be resubmitted. For 
example, resubmissions of data initially reported by March 31, 2025, 
used to assess WEC for the 2024 reporting year, would be required to be 
submitted by November 1, 2025. This proposed approach would not allow 
resubmissions for historic reporting years for WEC filings, even if 
their corresponding subpart W data was resubmitted for historic 
reporting years for purposes of subpart W. Subpart W facilities would 
continue to be subject to part 98 existing requirements for 
resubmitting data for previous reporting years, but any data 
resubmitted under part 98 after November 1 of the calendar year 
following the respective reporting year would not be considered for the 
purposes of WEC under part 99. This deadline would apply to all WEC 
applicable facilities, including those with data verified by EPA. The 
EPA's proposed approaches for WEC filing requirements and data 
verification are intended to incentivize complete and accurate WEC 
filings under part 99, and thus corresponding reporting of complete and 
accurate data under part 98, by March 31 of each year. As a result, the 
EPA expects that there will be little need to resubmit data after this 
initial reporting deadline, and the seven months between March 31 and 
the proposed final deadline of November 1 would give facility owners or 
operators sufficient time to make any resubmissions. The EPA proposes 
that it would retain the right to reevaluate WEC obligations in WEC 
filings after November 1 (e.g., as part of an EPA audit of facility 
data). Similarly, the November 1 deadline would not apply to 
adjustments to WEC obligations resulting from the process to resolve 
unverified data, proposed at 40 CFR 99.8, should that resolution occur 
after November 1.
    The EPA requests comment on the proposed approach of setting a 
deadline for WEC resubmissions under part 99 and in doing so not 
allowing data resubmissions for the WEC filing for previous historic 
reporting years. The EPA requests comment on the November 1 deadline 
and options for alternative deadlines. The EPA also requests comment on 
alternative approaches that would allow data resubmissions for historic 
reporting years under the WEC program, as well as comment on how such 
changes would be incorporated into netting for historic reporting 
years.

[[Page 5352]]

B. Remittance and Assessment of WEC

    We are proposing that each WEC obligation payment must be submitted 
electronically in accordance with the proposed requirements of 40 CFR 
99.6 and in a format specified by the Administrator as part of the 
submission of the WEC filing (i.e., by March 31 each year covering the 
preceding reporting year).
    For the purposes of ensuring timely payment of the WEC, the EPA is 
proposing financial sanctions under 40 CFR 99.10 of subpart A, pursuant 
to the authority included in the Federal claims provision at 31 U.S.C. 
3717. These penalties would apply to delinquent WEC payments. Under 31 
U.S.C. 3717, there are interest, penalties, and costs that may be 
imposed on outstanding or delinquent debts arising under a claim owed 
by a person to the U.S. Government. Specifically, under 31 U.S.C. 
3717(a)(1), agencies shall charge a minimum annual rate of intereston 
an outstanding debt on a United States Government claim owned by a 
person.\41\ Under the EPA's implementing Policy Number 2540-9-P2, 
accounts are considered delinquent when the EPA does not receive 
payment by the due date specified on a bill or invoice (i.e., for the 
WEC obligation at the time of submission of the WEC filing). The EPA is 
proposing to cite this Federal claims interest charge authority as the 
first tier of WEC payment sanctions.
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    \41\ This rate of interest is known as the Current Value of 
Funds Rate, or CVFR, and is published prior to November 30th of each 
year by Treasury. The CVFR is based on the weekly average of the 
Effective Federal Funds Rate, less 25 basis points, for the 12-month 
period ending September 30th of each year, rounded to the nearest 
whole percent. This rate may be revised on a quarterly basis if the 
annual average, on a moving basis, changes by 2 percentage points or 
more.
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    Second, under 31 U.S.C. 3717(e)(1), agencies must collect an 
additional penalty charge of not more than six percent per year for 
failure to pay any part of a debt more than 90 days past due, as well 
as additional charge to cover the cost of processing delinquent claims. 
Under Policy Number 2540-9-P2, the EPA Finance Centers are responsible 
for issuing demand notices and conducting collection efforts for the 
Agency. The EPA Finance Centers would assess interest, handling, and 
penalty charges in 30-day increments for late payments and would assess 
the 6 percent penalty with the 3rd demand letter or notice.
    The EPA therefore proposes to include this additional 6 percent 
non-payment penalty charge for WEC debts that are more than 90 days 
past due. This would be the second tier of sanction authority under 
this proposal's set of payment sanctions and would be implemented if 
the first tier of interest charges is not effective in causing a 
delinquent WEC obligated party to make their payments current. The EPA 
seeks comment on its proposed approach for applying interest to late 
WEC fee payments.
    Additionally, for WEC obligated parties that fail to submit their 
annual WEC filing by the deadline discussed in section III.A.2. of this 
preamble, the EPA is proposing a daily penalty no greater than the rate 
associated with 42 U.S.C. 7413(d)(1) specified in Table 1 of 40 CFR 
19.4, as amended. The EPA Finance Centers would assess interest, 
handling, and penalty charges in 30-day increments. We are proposing 
that the assessment of this penalty would begin on the date that the 
WEC filing was considered past due (i.e., April 1st) and continue until 
such time that the WEC filing is submitted and certified by the WEC 
obligated party. The EPA requests comment on its proposed approach of 
establishing a daily penalty for unsubmitted WEC filings.
1. Process for Reassessing WEC for WEC Filings Resubmitted After the 
Initial Waste Emission Charge Has Been Assessed
    As discussed in section III.A.4. of this preamble, WEC obligated 
parties may need to resubmit their WEC filings and WEC applicable 
facilities may need to resubmit their GHGRP reports. These resubmittals 
have the potential to result in recalculation of the WEC obligation for 
the WEC obligated party. As discussed in section III.A.4. of this 
preamble, the EPA proposes that data resubmissions for the previous 
reporting year would be required to be submitted by November 1 in order 
to be considered for WEC recalculations, with the exeption of 
resubmissions related to CAA section 111(b) or (d) compliance reports 
for the purposes of the regulatory compliance exemption. If the 
recalculated WEC obligation is less than the original WEC obligation 
owed by the WEC obligated party, we propose that the EPA would 
authorize a refund to the WEC obligated party equal to the difference 
in WEC obligation. If the recalculated WEC obligation is greater than 
the original WEC obligation owed by the WEC obligated party, the EPA 
would charge the WEC obligated party for the remaining balance of the 
WEC, including any assessed fees or penalties.\42\ To encourage careful 
attention to detail and reduce the need for WEC filing revisions, we 
are proposing to charge a daily interest rate for any revised WEC 
filing that results in additional WEC being owed. As proposed in 40 CFR 
99.8, this daily interest rate would be assessed from April 1st (i.e., 
the day after the submission deadline) until such time that a 
resubmitted WEC filing and payment, that is subsequently verified by 
the EPA, is certified by the designated representative. We propose a 
daily interest rate equal to the Current Value of Funds Rate, 
consistent with 31 U.S.C. 3717(a). The EPA proposes that payment for 
any additional WEC, including assessed interest, would made with the 
resubmitted WEC filing.
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    \42\ We propose that WEC obligated parties would be subject to 
the financial sanctions proposed in 40 CFR 99.10 for any delinquent 
payments of the revised WEC invoice(s), as discussed in section 
III.B. of this preamble.
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    The EPA seeks comment on the proposed approach for resubmitted WEC 
filings, including the application of daily interest rate for revised 
WEC filings that result in additional WEC being owed.
2. Process for Assessing WEC for Unverified Part 99 Filings
    As discussed in section III.A.4. of this preamble, the EPA's 
verification review process ideally ends with the resolution of 
identified potential errors through either correction and resubmission 
of facilities' reports or justification provided through correspondence 
with reporters that no substantive error exists. When WEC applicable 
facilities or WEC obligated parties do not provide appropriate 
information to resolve the errors in their part 98 or part 99 data 
after 45 days (with the possibility of a 30-day extension) of either 
being contacted in writing by the EPA notifying them of the presence of 
a substantive error or by self-discovering that a previously submitted 
part 98 report or WEC filing contains one or more substantive errors, 
the EPA considers their WEC filing to be unverified.
    If a WEC filing is unverified but the EPA is able to correct the 
error(s) based on reported data, we propose that the EPA will 
recalculate the WEC using available information and provide an invoice 
or refund to the WEC Obligated Party within 60 days of determining a 
WEC filing to be unverified. If the WEC Obligated Party resubmits a WEC 
filing within that timeframe, the EPA would either accept the 
resubmission, or take the resubmission into account when calculating 
the WEC. In cases where the EPA is unable to calculate the WEC with 
available information, the WEC Obligated Party may be required to

[[Page 5353]]

undergo a third-party audit. The third-party auditor must review 
records kept by the WEC Obligated Party, quantify the WEC with 
available information and in accordance with the requirements of this 
part, and submit the updated WEC calculations and supporting data to 
the EPA. The EPA would then take that information into consideration 
and calculate the WEC and provide an invoice to the WEC Obligated 
Party. Third-party audits may be required to be arranged by and 
conducted at the expense of the WEC obligated party.
    A WEC obligated party would be required to pay an invoice received 
from the EPA for any updated WEC obligation by the specified due date, 
or within 30 days of the date of the invoice or bill if a due date is 
not provided.
    The EPA requests comment on the proposed approach for assessing WEC 
for unverified part 99 reports, including the EPA recalculating WEC 
when data are available, and the option of requiring third-party 
auditing of WEC obligated party records when the EPA is not able to 
recalculate WEC with the available information. The EPA requests 
comment on an alternative approach that would establish default values 
(e.g., industry segment-specific methane intensities) that would be 
conservative in nature and used to calculate WEC applicable emissions 
from unverified reports until such time that the report becomes 
verified. The calculated methane emissions from the unverified 
report(s) would then be included when determining the WEC obligated 
party's WEC obligation. In this approach, the EPA envisions that 
similar financial sanctions as those discussed in section III.B.2. of 
this preamble would be applied until a verified report is submitted and 
certified by the WEC applicable facility. We also seek comment on 
additional gap-filling approaches for unverified GHGRP reports. In 
addition, the EPA seeks comment on an approach for unverified reports 
that would apply daily penalties on unverified reports, up to the rate 
associated with U.S. Code citation 42 U.S.C. 7413(d)(1) specified in 
Table 1 of 40 CFR 19.4, as amended. Under such an approach, the EPA 
seeks comment on the duration of the penalty (e.g., 3 years or until 
the report is verified, whichever is sooner).

C. Authorizing the Designated Representative

    We are proposing provisions for each affected WEC obligated party 
to identify a designated representative. We are proposing that each WEC 
obligated party would each have one designated representative who is an 
individual selected by an agreement binding on the WEC obligated party. 
This designated representative would act as a legal representative 
between the WEC obligated party and the Agency. We are proposing that 
the designated representative must submit a complete certificate of 
representation at least 60 days prior to the submission of the first 
WEC filing made by the WEC obligated party. Additionally, each WEC 
filing would contain a signed certification by a designated 
representative of the WEC obligated party. On behalf of the owner or 
operator, the designated representative would certify under penalty of 
law that the WEC filing has been prepared in accordance with the 
requirements of 40 CFR part 99 and that the information contained in 
the WEC filing is true and accurate, based on a reasonable inquiry of 
individuals responsible for obtaining the information.
    We are also proposing that the designated representative could 
appoint an alternate to act on their behalf, but the designated 
representative would maintain legal responsibility for the submission 
of complete, true, and accurate emissions data and supplemental data. A 
designated representative or alternate designated representative may 
delegate one or more ``agents.'' The agent (e.g., a part 98 subpart W 
designated representative who can provide facility-specific 
information) can enter data for a part 99 WEC filing, but is not 
allowed to submit, certify, or sign a WEC filing.
    We are proposing that within 90 days after any change in the WEC 
obligated party, the designated representative or any alternate 
designated representative must submit a certificate of representation 
that is complete under this section to reflect the change.

D. General Recordkeeping Requirements

    We are proposing that WEC applicable facilities and WEC obligated 
parties must retain all required records for at least 5 years from the 
date of submission of the WEC report for the reporting year in which 
the record was generated. We are proposing that the records shall be 
kept in an electronic or hard-copy format (as appropriate) and recorded 
in a form that is suitable for expeditious inspection and auditing. 
Under the proposed provisions, upon request by the Administrator, the 
records required under this section must be made available to the EPA. 
We are proposing that records may be retained off site if the records 
are readily available for expeditious inspection and review. For 
records that are electronically generated or maintained, we are 
proposing that the equipment or software necessary to read the records 
shall be made available, or, if requested by the EPA, electronic 
records shall be converted to paper documents. The records that the EPA 
is proposing that must be retained would include information required 
to be retained under part 98, specifically subparts A and W, any other 
information needed to complete the WEC filing, and all information 
required to be submitted as part of the WEC filing, including any 
supporting documentation.

E. General Provisions, Including Auditing and Compliance and 
Enforcement

1. Auditing Provisions
    We are proposing that the EPA may conduct on-site audits of 
facilities, as indicated in 40 CFR 99.7(c). Under the proposed general 
recordkeeping provision at 40 CFR 99.7(d), the records generated under 
this part would be available to the EPA during an on-site audit as the 
records must be recorded in a form that is suitable for expeditious 
inspection and review, and must be made available to the EPA upon 
request. The on-site audits may be conducted by private auditors 
contracted by the EPA or by Federal, State or local personnel, as 
appropriate, and may be required to be arranged by and conducted at the 
expense of the WEC obligated party.
2. Compliance and Enforcement
    We are proposing that any violation of any requirement of this part 
shall be a violation of the Clean Air Act, including section 114 (42 
U.S.C. 7414) and section 136 (42 U.S.C. 7436). A violation would 
include but is not limited to failure to submit, or resubmit as 
required, a WEC filing, failure to collect data needed to calculate the 
WEC charge (including any data relevant to determining the 
applicability of any exemptions), failure to retain records needed to 
verify the amount of WEC charge, providing false information in a WEC 
filing, and failure to remit WEC payment. As proposed at 40 CFR 
99.4(b), it is a violation to fail to authorize a designated 
representative for a WEC obligated party. In the case of a facility 
with more than one owner or operator, failure to select a WEC obligated 
part would constitute a violation on the part of each owner or 
operator, as proposed at 40 CFR 99.4. Each day of a violation would 
constitute a separate violation.

[[Page 5354]]

IV. Proposed Confidentiality Determinations for Certain Data Reporting 
Elements

A. Overview and Background

    In this action, the EPA is proposing to require WEC obligated 
parties to report the general information described in section III.A.3. 
of this preamble and the information specific to any applicable 
exemptions as described in sections II.D.1. through 3. of this 
preamble. This information is necessary for the EPA to verify the 
contents of the WEC filing, including confirming that all of the 
required WEC applicable facilities were included, each WEC applicable 
facility is eligible for any exemptions that were applied, and the WEC 
applicable emissions and the amount of the WEC obligation were 
calculated correctly. As explained in the remainder of this section, 
the EPA is proposing that nearly all of the data reported would be 
either emission data or otherwise ineligible for confidential 
treatment. The information that may be eligible for confidential 
treatment would be information included in supporting documentation 
required for eligible exemptions or additional information provided in 
software comments fields.
    Section 114(c) of the CAA requires that ``[a]ny records, reports, 
or information obtained under [CAA section 114(a)] shall be available 
to the public, except that upon a showing satisfactory to the 
Administrator by any person that records, reports, or information, or 
particular part thereof, (other than emission data) . . . if made 
public, would divulge methods or processes entitled to protection as 
trade secrets . . . , the Administrator shall consider such record, 
report, or information or particular portion thereof confidential. . . 
.'' Thus, the CAA begins with a presumption that information submitted 
to the EPA may be disclosed to the public. It then provides a narrow 
exception to that presumption for information that ``if made public, 
would divulge methods or processes entitled to protection as trade 
secrets. . . .'' Section 114(c) of the CAA narrows this exception 
further by excluding ``emission data'' from the category of information 
eligible for confidential treatment. The EPA has interpreted CAA 
section 114(c) to afford confidential treatment to both trade secrets 
and confidential business information that are not emission data (40 FR 
21987, 21990 (May 20, 1975)).
    While the CAA does not define ``emission data,'' the EPA has done 
so by regulation at 40 CFR 2.301(a)(2)(i). Emission data means, with 
reference to any source of emissions of any substance into the air--
    (A) Information necessary to determine the identity, amount, 
frequency, concentration, or other characteristics (to the extent 
related to air quality) of any emission which has been emitted by the 
source (or of any pollutant resulting from any emission by the source), 
or any combination of the foregoing;
    (B) Information necessary to determine the identity, amount, 
frequency, concentration, or other characteristics (to the extent 
related to air quality) of the emissions which, under an applicable 
standard or limitation, the source was authorized to emit (including, 
to the extent necessary for such purposes, a description of the manner 
or rate of operation of the source); and
    (C) A general description of the location and/or nature of the 
source to the extent necessary to identify the source and to 
distinguish it from other sources (including, to the extent necessary 
for such purposes, a description of the device, installation, or 
operation constituting the source).
    Further, in a 1991 EPA notice of policy (56 FR 7042, February 21, 
1991), the EPA stated that certain data fields constitute ``emission 
data'' and therefore cannot be withheld as confidential. The 1991 
document indicated that while confidentiality determinations are 
typically made on a case-by-case basis, some kinds of data will always 
constitute emission data within the meaning of CAA section 114(c). The 
document listed several data fields that EPA considered to be emission 
data including facility identification data (e.g., facility name; 
address; ownership; Standard Industrial Classification (SIC); emission 
point, device or operation description information) and emission 
parameters (e.g., compounds emitted; origin of emissions; emission 
rate, concentration, release parameters, boiler or process design 
capacity, emission estimation method). The document clarified that the 
list of types of information in the document was not exhaustive and 
that other data might also constitute emission data.
    For data that are not ``emission data,'' the confidentiality 
determination criteria at 40 CFR 2.208(a) through (d) are as follows:
    Determinations issued under Sec. Sec.  2.204 through 2.207 shall 
hold that business information is entitled to confidential treatment 
for the benefit of a particular business if:
    (a) The business has asserted a business confidentiality claim 
which has not expired by its terms, nor been waived nor withdrawn;
    (b) The business has satisfactorily shown that it has taken 
reasonable measures to protect the confidentiality of the information, 
and that it intends to continue to take such measures;
    (c) The information is not, and has not been, reasonably obtainable 
without the business's consent by other persons (other than 
governmental bodies) by use of legitimate means (other than discovery 
based on a showing of special need in a judicial or quasi-judicial 
proceeding); and
    (d) No statute specifically requires disclosure of the information.
    In Food Marketing Institute v. Argus Leader Media, 139 S. Ct. 2356 
(2019) (hereafter referred to as Argus Leader), the U.S. Supreme Court 
issued an opinion addressing the meaning of the word ``confidential'' 
in Exemption 4 of the Freedom of Information Act, 5 U.S.C. 
552(b)(4)(2012 and Supp. V. 2017) stating that ``confidential'' must be 
given its ``ordinary'' meaning, which is information that is 
``private'' or ``secret.'' As a result, starting with the date of the 
Argus Leader ruling, the EPA no longer assesses data elements using the 
rationale of whether disclosure will cause a likelihood of substantial 
competitive harm when making confidentiality determinations. Instead, 
the EPA assesses whether the information is customarily and actually 
treated as private by the reporter and whether the EPA has given an 
assurance at the time the information was submitted that the 
information will be kept confidential or not confidential.

B. Proposed Confidentiality Determinations

    Pursuant to CAA section 114(c), the EPA is proposing to make 
categorical emission data and confidentiality determinations in advance 
through this notice and comment rulemaking for the categories of 
information in these proposed reports under part 99. We describe the 
proposed emission data categories and confidentiality determinations 
for the reported information, as well as the basis for such proposed 
determinations, in this section. This approach is similar to the 
approach we have taken for the GHGRP under 40 CFR part 98 (see 75 FR 
39094, July 7, 2010, and 75 FR 30782, May 26, 2011, for more 
information).
    The determinations the EPA is proposing in this rulemaking, if 
finalized, would serve as notification of the Agency's decisions 
concerning: (1) the categories of information the Agency will not treat 
as confidential because it is emission data; (2) the information that

[[Page 5355]]

is not emission data but is not entitled to confidential treatment; and 
(3) the information that the submitter may claim as confidential but 
will remain subject to the existing 40 CFR part 2 process. In 
responding to requests for information not determined in this proposal 
to be emission data or otherwise not entitled to confidential 
treatment, we propose to apply the default case-by-case process found 
in 40 CFR part 2.
    The emission data and confidentiality determinations proposed in 
this rulemaking are intended to provide consistency in the treatment of 
the information collected by the EPA as part of the proposed WEC 
filings. The EPA anticipates that making these determinations in 
advance through this rulemaking will provide predictability and 
transparency for both information requesters and submitters.
    The categories of information that we are proposing to determine to 
be emission data in this action are:
    (1) Methane emissions;
    (2) Calculation methodology; and
    (3) Facility and unit identifier information.
    The EPA is proposing to group types of information (data elements) 
that the Agency is proposing to require WEC obligated parties to submit 
under part 99 that would be considered emission data into these three 
categories based on their shared characteristics. For the sake of 
organization, for any information that logically could be grouped into 
more than one category, we have chosen to label information as being in 
just one category where we think it fits best. This approach will 
reduce redundancy within the categories that could lead to confusion 
and ensure consistency in the treatment of similar information in the 
future. We are requesting comment on the following: (1) our proposed 
categories of emission data; and (2) our placement of each data element 
under the category proposed.
    For reporting elements that the EPA does not designate as 
``emission data,'' the EPA is proposing to assess each individual 
reporting element according to the Argus Leader criteria (i.e., whether 
the information is customarily and actually treated as private by the 
submitter) and 40 CFR 2.208(a) through (d). Therefore, we are not 
proposing to establish categories and categorical confidentiality 
determinations for information that is not ``emission data.'' However, 
we are proposing descriptions of the type of information that would not 
be eligible for confidential treatment in 40 CFR 99.13(b), including 
certain information demonstrating compliance with standards and 
information that is publicly available. We are also proposing in 40 CFR 
99.13(c) through (e) to specify certain data elements and types of 
information that would be subject to the process for confidentiality 
determinations in 40 CFR part 2. The proposed provisions in 40 CFR 
99.13(b) would establish the proposed confidentiality determinations of 
the proposed data elements in part 99 and would also provide clarity 
and ensure consistent treatment of new or substantively revised data 
elements if the content of the WEC filing is amended in a future 
rulemaking. Sections IV.B.2. and 3. of this preamble describe these 
proposed provisions, and our assessment of each individual reporting 
element that we are proposing is not ``emission data.'' We are 
requesting comment on the proposed Agency determinations that 
information described in those sections of the preamble are not 
entitled to confidential treatment.
1. Emission Data
    We are proposing to establish in 40 CFR 99.13(a) that certain 
categories of information the EPA would collect in the proposed WEC 
filings are information that meets the regulatory definition of 
emission data under 40 CFR 2.301(a)(2)(i). The following sections 
describe the categories of information we are proposing to determine to 
be emission data, based on application of the definition at 40 CFR 
2.301(a)(2)(i) to the shared characteristics of the information in each 
category and our rationale for each proposed determination.
a. Information Necessary To Determine the Identity, Amount, Frequency, 
Concentration, or Other Characteristics of Emissions Emitted by the 
Source
    Under 40 CFR 2.301(a)(2)(i)(A), emission data includes 
``[i]nformation necessary to determine the identity, amount, frequency, 
concentration, or other characteristics (to the extent related to air 
quality) of any emission which has been emitted by the source (or of 
any pollutant resulting from any emission by the source), or any 
combination of the foregoing[.]'' We are proposing that the following 
categories of information are emission data under 40 CFR 
2.301(a)(2)(i)(A):
    (1) Methane emissions; and
    (2) Calculation methodology.
    Methane emissions. Data elements included in the Methane emissions 
data category are the net WEC emissions, facility waste emissions 
thresholds, industry segment waste emissions thresholds for each 
applicable industry segment within the facility (if more than one 
industry segment applies), and WEC applicable emissions, as well as the 
quantities of methane emissions that the WEC obligated party calculates 
should be exempted due to unreasonable delay and wells that were 
permanently shut-in and abandoned. The EPA proposes to determine that 
the emissions at each reporting level constitute ``emission data.'' 
These data elements are information regarding the identity, amount, and 
frequency of any emission emitted by the WEC applicable facility, and, 
therefore, they are ``emission data.'' As discussed in section IV.A. of 
this preamble, in the 1991 EPA notice of policy (56 FR 7042, February 
21, 1991), the EPA identified, without attempting to be comprehensive, 
data elements that the EPA considered to constitute emission data. The 
1991 document lists the ``Emission type (e.g., the nature of emissions, 
such as CO2, particulate or a specific toxic compound, and 
origin of emissions such as process vents, storage tanks or equipment 
leaks)'' and ``Emission rate (e.g., the amount released to the 
atmosphere over time such as kg/yr or lbs/yr)'' as data that are not 
entitled to confidential treatment and are, therefore, releasable to 
the public. Our proposed determination for this data category is 
consistent with the 1991 document. It is also consistent with the 
determination for a similar category in the GHGRP under 40 CFR part 98.
    Calculation methodology. The data element included in this category 
is the method used to determine the quantity of methane emissions that 
the WEC obligated party calculates should be exempt due to an 
unreasonable permitting delay and the method used to determine the 
equipment leaks emissions attributable to a plugged well. Most of the 
necessary calculations in part 99 do not include multiple equations or 
approaches that could be selected by a WEC obligated party, and in 
those cases, the calculation methodology used is readily apparent for 
any WEC obligated party. Calculations for the exemptions for 
unreasonable delay and plugged wells do include multiple equations that 
facilities may use under different circumstances.
    The EPA proposes to determine that the data elements in the 
Calculation methodology category are ``emission data'' under 
2.301(a)(2) because they are ``information necessary to determine . . . 
the amount'' of emissions emitted by the source. The method used to 
calculate emissions is emission data under 40 CFR 2.301(a)(2) because 
it is information necessary for the WEC obligated party to calculate 
the

[[Page 5356]]

emissions and for the EPA and the public to verify that an appropriate 
method was used. As discussed in section IV.A. of this preamble, the 
1991 EPA notice of policy provided a list of information that the EPA 
considered to constitute ``emission data'' under 40 CFR 
2.301(a)(1)(2)(i). That list includes the ``emission estimation method 
(e.g., the method by which an emission estimate has been calculated 
such as material balance, source test, use of AP-42 emission factors, 
etc.),'' which is the same type of data element as those that the EPA 
is proposing to include in this data category. Our proposed 
determination for this data category is consistent with the 1991 
document. It is also consistent with the determination for a similar 
category in the GHGRP under 40 CFR part 98.
b. Information That Is Emission Data Because It Provides a General 
Description of the Location and/or Nature of the Source to the Extent 
Necessary To Identify the Source and To Distinguish It From Other 
Sources
    Under 40 CFR 2.301(a)(2)(i)(C), emission data includes ``a 
``[g]eneral description of the location and/or nature of the source to 
the extent necessary to identify the source and to distinguish it from 
other sources (including, to the extent necessary for such purposes, a 
description of the device, installation, or operation constituting the 
source).'' We are proposing that the data elements in the Facility and 
unit identifier information category of information are emission data 
under 40 CFR 2.301(a)(2)(i)(C).
    The proposed part 99 regulations would require WEC obligated 
parties to report in the WEC filing information needed to identify each 
facility as well as specific emission units (affected facilities) and/
or well-pads associated with an exemption. Facility-identifying 
information must be reported for all facilities as specified in 40 CFR 
part 99, subpart A. Affected facility-specific identifying information 
is required for the regulatory compliance exemption. Well-pad-specific 
identifying information is reported if required by an applicable 
exemption for onshore petroleum and natural gas production facilities.
    Data elements in this category would include the following data 
elements required under 40 CFR part 99, subpart A to be included in 
each annual WEC filing: WEC obligated party company name and address, 
the name and contact information for the designated representative of 
WEC obligated party, and a signed and dated certification statement of 
the accuracy and completeness of the report, which is provided by the 
designated representative of the owner or operator. The proposed part 
99 regulations would also require that the filing include specific 
information about each facility covered by the annual WEC filing, 
including the e-GGRT ID number and the industry segment. For each 
exemption, the facility and unit identifier information category would 
include (as applicable) the facility identifier, the well-pad and/or 
well identifier reported under subpart W (if applicable), other 
facility or affected facility identifiers used to identify the 
facility/sources in other EPA systems (specifically, the ICIS-AIR ID or 
Facility Registry Service (FRS) ID and the EPA Registry ID from the 
Compliance and Emissions Data Reporting Interface (CEDRI)), emission 
source-specific methane mitigation activities impacted by an 
unreasonable permitting delay, and exemption-specific certification 
statements.
    As discussed in section IV.A. of this preamble, emission data must 
be available to the public and is not entitled to confidential 
treatment under CAA section 114(c). ``Emission data'' is defined in 40 
CFR 2.301(a)(2)(i)(C) to include ``[a] general description of the 
location and/or nature of the source to the extent necessary to 
identify the source and to distinguish it from other sources . . . .'' 
Consistent with this definition of emission data, the EPA considers 
facility and emission unit identifiers to be source information or 
``information necessary to determine the identity . . . of any emission 
which has been emitted by the source,'' and therefore emission data 
under 40 CFR 2.301(a)(2)(i). Further, 40 CFR 2.301(a)(2)(i)(A) 
specifies that emission data includes, among other things, 
``information necessary to determine the identity, amount, frequency, 
concentration, or other characteristics (to the extent related to air 
quality) of any emission which has been emitted by the source. . . .'' 
The EPA considers the term ``identity . . . of any emission'' as not 
simply referring only to the names of the pollutants being emitted, but 
to also include other identifying information, such as from what and 
where (e.g., the identity of the emission unit) the pollutants are 
being emitted.
    The 1991 EPA notice of policy (discussed in section IV.A. of this 
preamble) provided a list of data fields that the EPA considered to be 
emission data. For example, in the 1991 document, the EPA considered 
that plant name, address, city, State, zip code, emission point or 
device description, SIC code, and Source Classification Code (SCC) are 
emission data. Therefore, the public has been on notice that the EPA 
considers many of the data elements in this data category to be 
emission data and thus not entitled to confidential treatment. The 1991 
document also makes clear that the list of data is not comprehensive 
and that other data might also constitute emission data. This proposed 
part 99 determination that these data elements are emission data is 
consistent with the 1991 policy statement, and also consistent with the 
Facility and unit identifier information category in the GHGRP under 40 
CFR part 98.
2. Reported Information That Is Never Entitled to Confidential 
Treatment
    As noted in section IV.B. of this preamble, we are proposing to 
assess the confidentiality of each individual part 99 reporting element 
that is not otherwise designated as emission data in this rulemaking 
according to the Argus Leader criteria (i.e., whether the information 
is customarily and actually treated as private by the submitter) and 40 
CFR 2.208(a) through (d). However, in this action we are proposing 
descriptions of the type of information that would not be eligible for 
confidential treatment in 40 CFR 99.13(b), in part to establish the 
proposed confidentiality determinations of the proposed data elements 
in part 99 but also to provide clarity and consistency in the event 
that the content of the WEC filings are amended in a future rulemaking. 
The WEC obligation is calculated by multiplying the net WEC emissions 
by a set dollar amount, depending on the reporting year. As explained 
in section IV.B.1.a. of this preamble, the EPA is proposing to 
determine that the net WEC emissions are emission data. Therefore, we 
are proposing that the WEC obligation, which is calculated as the net 
WEC emissions multiplied by a dollar per ton rate that is prescribed in 
CAA section 136, would not be eligible for confidential treatment.
    We are also proposing that certain information considered to be 
compliance information in part 99, regardless of whether it is or is 
not designated as emission data, is still not otherwise eligible for 
confidential treatment. Compliance information collected under part 99 
includes information necessary to demonstrate compliance with the 
eligibility requirements for the exemptions for unreasonable permitting 
delay, regulatory compliance, and wells that have been permanently 
shut-in and plugged. Examples of the information collected include: for 
the unreasonable

[[Page 5357]]

delay exemption, the date of the permit request, the estimated date to 
commence operation if the application had been approved within a set 
period of months, the first date that offtake to the gathering or 
transmission infrastructure from the implementation of methane 
emissions mitigation occurred once the application was approved, the 
beginning and ending date for which the eligible delay limited the 
offtake of natural gas associated with methane emissions mitigation 
activities, information on all applicable local, state, and Federal 
regulations regarding flaring emissions and the facility's compliance 
status for each, and other compliance information related to gathering 
or transmission infrastructure; for the regulatory compliance 
exemption, copies of reports and other evidence of compliance with NSPS 
OOOOb or a state, Tribal, or Federal plan under 40 CFR part 62; and for 
the plugged well exemption, the date a well was permanently shut-in and 
plugged and the statutory citation for the requirements that were 
followed for that process. Operating and construction permits are 
available to the public through the State issuing the permits (as the 
delegated authority of the EPA), generally either through an online 
information system or website, or upon request to the state agency 
issuing the permits. These permits are expected to contain information 
about the type and size of process equipment operated at a facility, 
control devices or other measures undertaken to reduce emissions from 
each process, and the emission standards to which the facility is 
subject (including Federal standards as well as state or local 
standards). Reports submitted by owners and operators of facilities 
subject to NSPS OOOOb or a state, Tribal, or Federal plan under 40 CFR 
part 62 are available through the EPA's online repository ``WebFIRE.'' 
See https://www.epa.gov/electronic-reporting-air-emissions/webfire. 
Finally, well-specific information, including age, production rate, and 
operating status, is publicly available through state oil and gas 
commissions and/or state databases as well as sources such as Enverus. 
Because this information is already publicly available, it would not be 
eligible for confidential treatment.
    The EPA is also proposing in 40 CFR 99.13(b)(3) that any other 
information that has been published and made publicly available, 
including the publicly available reports submitted under the GHGRP and 
information on websites, would not be eligible for confidential 
treatment. Information that is publicly available does not meet the 
criteria for information entitled to confidential treatment specified 
in 40 CFR 2.208(c). This proposed paragraph 40 CFR 99.13(b)(3) would 
specify an additional type of information that would not be eligible 
for confidential treatment when evaluating the confidentiality of 
supporting documentation submitted as described in proposed 40 CFR 
99.13(c) or (d) (see section IV.B.3. for additional information on 
supporting documentation).
3. Information for Which the EPA Is Not Proposing a Confidentiality 
Determination
    This section describes information for which the EPA is not 
proposing a confidentiality determination. The EPA would initially 
treat this information as confidential upon receipt, if the submitter 
claimed it as such, until a case-by-case determination is made by the 
Agency under the 40 CFR part 2 process.
    We do not expect emission data to be submitted in supporting 
documentation, but we are proposing that information in supporting 
documentation as described in proposed 40 CFR 99.13(c) (i.e., 
information not listed in proposed 40 CFR 98.13(a) or (b) as not 
eligible for confidential treatment) would be treated as confidential 
until a case-by-case determination is made under the 40 CFR part 2 
process. The EPA is also proposing that information provided in 
software comments fields as described in proposed 40 CFR 99.13(d) would 
not be eligible for confidential treatment if it is listed in proposed 
40 CFR 98.13(a) or (b) as not eligible for confidential treatment. 
Otherwise, the EPA would treat the information as confidential until a 
case-by-case determination is made under the 40 CFR part 2 process, as 
specified in proposed 40 CFR 99.13(c). The EPA recognizes that 
supporting documentation and reporter comments may include information 
that is sensitive or proprietary, such as detailed process designs or 
site plans. Because the exact nature of this documentation cannot be 
predicted with certainty, the EPA proposes to make case-by-case 
confidentiality determinations under CAA section 114(c) for any 
supporting documentation or comments claimed confidential by applicants 
either upon receipt of such information or upon a request for such 
information after receipt.

C. Proposed Amendments to 40 CFR Part 2

    As previously discussed, pursuant to CAA section 114(c), the EPA 
must make available to the public data submitted under part 99, except 
for data (other than emission data) that are considered confidential 
under CAA section 114(c). Accordingly, the EPA may release part 99 data 
without further notice after submission to the EPA in accordance with 
the EPA's determinations of their confidentiality status in the final 
rule. Specifically, the EPA may release part 99 data that are 
determined in the final rule to be emission data or not otherwise 
entitled to confidential treatment under CAA section 114(c) (i.e., 
``non-CBI''). For data elements that we determine to be entitled to 
confidential treatment under CAA section 114(c), the EPA would release 
or publish such data only if the information can be aggregated in a 
manner that would protect the confidentiality of these data at the 
facility level. Existing regulations in 40 CFR part 2, subpart B set 
forth procedural steps that the EPA must follow before releasing any 
information, either on the Agency's own initiative or in response to 
requests made pursuant to FOIA. In particular, the EPA is generally 
required to make case-by-case confidentiality determinations and to 
notify individual reporters before disclosing information that 
businesses have submitted with a confidentiality claim. As discussed in 
section IV.B of this preamble, in light of the voluminous data the EPA 
receives under subpart W of part 98 and the multiple procedural steps 
required under 40 CFR part 2, subpart B, the EPA would not be able to 
make part 99 data (determined to be emission data or non-CBI) publicly 
available in a timely fashion if it were required to make separate 
confidentiality determinations based on each submitter's individual 
claim of confidentiality.
    To facilitate timely release of GHG data collected under part 99 
that are emission data or non-CBI, the EPA proposes to amend 40 CFR 
2.301, Special rules governing certain information obtained under the 
Clean Air Act. Specifically, the EPA is proposing to revise 40 CFR 
2.301(d) to specify that the special rules for data submitted under 
part 98 would also apply to part 99. Under the proposed amendment, the 
EPA may release part 99 data that are determined to be emission data or 
information determined to be not entitled to confidential treatment 
upon finalizing the confidentiality status of these data.

[[Page 5358]]

Consistent with the 40 CFR part 2 procedures, the approach proposed in 
this rulemaking would provide the WEC obligated party an opportunity to 
justify and substantiate any confidentiality claim they may have for 
the data they are required to submit (except for emission data and 
other data not entitled to confidential treatment pursuant to CAA 
section 114(c)). In addition, WEC obligated parties have the benefit of 
seeing the EPA's rationales and analyses prior to submitting any 
justification, information that they would not otherwise have under the 
current 40 CFR part 2 procedures. As more fully explained in section 
IV.E of this preamble, the WEC obligated party must provide comment 
explaining why it disagrees with the rationale provided by the EPA for 
each particular data element it intends to claim confidential and must 
provide information to explain how the business customarily and 
actually treats the information as confidential. The EPA will consider 
comments received on this proposal before finalizing the 
confidentiality determinations.
    The EPA solicits comment on the proposed amendments to 40 CFR 
2.301(d), Special rules governing certain information obtained under 
the CAA for data submitted under part 99.

D. Proposed Changes to Confidentiality Determinations for Data Elements 
Reported Under Subpart W

    The industry segment waste emissions thresholds are calculated 
pursuant to 40 CFR 99.20. Except for facilities in the Offshore 
Petroleum and Natural Gas Production industry segment or the Onshore 
Petroleum and Natural Gas Production industry segment that have no 
natural gas sent to sale, each threshold is calculated by multiplying 
the specified natural gas throughput for that industry segment by two 
constant values, the density of methane and the industry segment-
specific methane intensity threshold (as summarized in Table 2 of this 
preamble). As noted in section IV.B.1.a. of this preamble, the EPA is 
proposing that the facility waste emissions thresholds and industry 
segment waste emissions thresholds are emission data and would 
therefore be made publicly available. For two industry segments, 
Onshore Natural Gas Processing and Onshore Natural Gas Transmission 
Compression, throughput quantities similar to those specified in the 
industry segment waste emissions threshold calculations have 
historically not been made publicly available under subpart W. However, 
for WEC applicable facilities, once the industry segment-specific waste 
emissions thresholds are made publicly available, the throughputs can 
be calculated based on available information.
    Therefore, the EPA is proposing to address confidentiality 
determinations for two subpart W data elements as part of this 
rulemaking. For the Onshore Natural Gas Processing industry segment, a 
new data element was proposed as part of 2023 Subpart W Proposal, the 
quantity of residue gas leaving that has been processed by the facility 
and any gas that passes through the facility to sale without being 
processed by the facility in the calendar year, in thousand standard 
cubic feet, reported under proposed Sec.  98.236(aa)(3)(ix). The EPA 
made a final determination in 79 FR 70352 (November 25, 2014) that the 
quantity of natural gas received at the gas processing plant in the 
calendar year (reported under 40 CFR 98.236(aa)(3)(i)) and the quantity 
of processed (residue) gas leaving the gas processing plant (reported 
under 40 CFR 98.236(aa)(3)(ii)), should be maintained as confidential. 
As explained in 79 FR 70352 (November 25, 2014), the reporting of this 
information to the Energy Information Administration is less frequent 
than required under subpart W, and the EPA had not identified any 
reliable public sources of the quantity of residue gas produced. In the 
June 2023 memorandum Proposed Confidentiality Determinations and 
Emission Data Designations for Data Elements in Proposed Revisions to 
the Greenhouse Gas Reporting Rule for Petroleum and Natural Gas Systems 
(Docket ID No. EPA-HQ-OAR-2023-0234-0167), the EPA stated that the 
proposed new data element under 40 CFR 98.236(aa)(3)(ix) would collect 
similar information to 40 CFR 98.236(aa)(3)(ii). As a result, the EPA 
proposed to determine that the information collected under 40 CFR 
98.236(aa)(3)(ix) would be eligible for confidential treatment.
    However, if the EPA finalizes the proposed determination that the 
industry segment-specific waste emissions thresholds are emission data, 
then those industry segment-specific waste emissions thresholds would 
be made publicly available as emission data. Therefore, the EPA is no 
longer proposing a confidentiality determination for this throughput 
quantity data element (i.e., the quantity of residue gas leaving that 
has been processed by the facility and any gas that passes through the 
facility to sale without being processed by the facility in the 
calendar year) under part 98. The confidentiality status of this data 
element would be evaluated on a case-by-case basis, in light of any 
publicly available information and in accordance with the existing 
regulations in 40 CFR part 2, subpart B, upon receipt of a public 
request for these data elements.
    For Onshore Natural Gas Transmission Compression, the EPA 
previously decided in 2014 not to make a confidentiality determination 
that would apply for all facilities for 40 CFR 98.236(aa)(4)(i), the 
quantity of gas transported through a compressor station. In 79 FR 
70352 (November 25, 2014), the EPA explained that we proposed that this 
data element would not be eligible for confidential treatment because 
natural gas transmission sector is heavily regulated by FERC and state 
commissions, resulting in a lack of competition between companies. 
However, we received comments from this industry sector noting that 
FERC Order 636 had introduced greater competition to this sector and 
that some companies charge customers less than the FERC approved rates 
because of competitive market pressures. The commenters indicated that 
quantity of gas transported through the compressor station would 
provide information on the quantity of gas transported by a specific 
pipeline, which may potentially cause competitive harm to some pipeline 
companies operating in more competitive market areas. Since the 
determination would depend on the particular market conditions for each 
company, the EPA did not make a determination for the data element that 
would apply for all reporters.\43\
---------------------------------------------------------------------------

    \43\ Prior to Argus Leader, the EPA considered whether the 
business had satisfactorily shown that disclosure of the information 
is likely to cause substantial harm to the business's competitive 
position when evaluating claims of confidentiality.
---------------------------------------------------------------------------

    In this rulemaking, the EPA is not proposing to change that 
previous decision and is still not proposing a confidentiality 
determination for the quantity of natural gas transported through a 
compressor station. While the Supreme Court's 2019 decision in Argus 
Leader altered the review criteria for confidentiality determinations 
from the Agency's 2014 decision, the basis provided by commenters to 
justify the confidential nature of the information is still relevant. 
For information pertaining to the quantity of gas transported through a 
compressor station collected under part 99, the EPA will conduct 
reviews of any claims made under the existing regulations in 40 CFR 
part 2, subpart B, upon receipt of a public request for this 
information. Any such reviews will consider the public availability of 
the same or similar

[[Page 5359]]

information, including WEC filings, as part of the determination 
process.

E. Request for Comments on Proposed Category Assignments, 
Confidentiality Determinations, or Reporting Determinations

    This rulemaking provides affected entities that would be subject to 
part 99, other stakeholders, and the general public an opportunity to 
provide comment on the proposed amendment to 40 CFR 2.301(d) and the 
proposed confidentiality determinations for part 99 data, including our 
proposed categories of emission data and the proposed confidentiality 
determinations for each data element that is not considered emission 
data. By proposing emission data and confidentiality determinations 
prior to data reporting through this proposal and rulemaking process, 
we are providing potentially affected entities an opportunity to submit 
comments, particularly comments addressing any data elements not 
entitled to confidential treatment under this proposal, but which 
companies customarily and actually treat as private. This opportunity 
to submit comments is intended to provide reporters with the 
opportunity to substantiate their confidentiality claims that would 
ordinarily be afforded when the EPA considers claims for confidential 
treatment of information in case-by-case confidentiality determinations 
under 40 CFR part 2. In addition, the comment period provides an 
opportunity to respond to the EPA's proposed determinations with more 
information for the Agency to consider prior to finalization. We will 
evaluate the comments on our proposed determinations, including claims 
of confidentiality and information substantiating such claims, before 
finalizing the confidentiality determinations. Please note that this 
will be reporters' only opportunity to substantiate a confidentiality 
claim for data elements included in this proposed rule where 
information being reported is proposed to be not entitled to 
confidential treatment. Upon finalizing the confidentiality 
determinations and reporting determinations of the data elements 
identified in this proposed rule, the EPA plans to release or withhold 
these data without further notice in accordance with proposed 40 CFR 
2.301(d), which contains special provisions governing the treatment of 
part 99 data for which confidentiality determinations have been made 
through rulemaking pursuant to CAA sections 114, 136, and 307(d).
    When submitting comments regarding the confidentiality 
determinations we are proposing in this action, please identify each 
individual proposed data element on which you are commenting and 
whether you consider the element to be confidential or do not consider 
to be ``emission data'' in your comments. If the data element has been 
designated as ``emission data,'' please explain why you do not believe 
the information meets the definition of ``emission data'' as defined in 
40 CFR 2.301(a)(2)(i). If the data has not been designated as 
``emission data'' and is proposed to not be entitled to confidential 
treatment, please explain specifically how the data element is 
commercial or financial information that is both customarily and 
actually treated as private. Particularly describe the measures 
currently taken to keep the data confidential and how that information 
has been customarily treated by your company and/or business sector in 
the past. This explanation is based on the requirements for 
confidential treatment set forth in Argus Leader.
    Members of the public may also discuss how this data element may be 
different from or similar to data that are already publicly available, 
including data already collected and published annually by the GHGRP, 
as applicable. Please submit information identifying any publicly 
available sources of information containing the specific data elements 
in question. Data that are already available through other sources 
would likely be found not to qualify for confidential treatment. In 
your comments, please identify the manner and location in which each 
specific data element you identify is publicly available, including a 
citation. If the data are physically published, such as in a book, 
industry trade publication, or Federal agency publication, provide the 
title, volume number (if applicable), author(s), publisher, publication 
date, and International Standard Book Number (ISBN) or other 
identifier. For data published on a website, provide the address of the 
website, the date you last visited the website and identify the website 
publisher and content author. Please avoid conclusory and 
unsubstantiated statements, or general assertions regarding the 
confidential nature of the information.
    In addition to soliciting comment on our proposed confidentiality 
designations and proposed amendments to 40 CFR 2.301, we are also 
soliciting comment on the following specific issues relevant to the 
proposed confidentiality determinations:
    ``Emission Data'' determination. As previously discussed, 
``emission data'' cannot be kept confidential per CAA section 114. The 
EPA is seeking comment on the part 99 data elements proposed to be 
considered ``emission data.'' Please specify exactly what part 99 data 
you think should be considered emission data, describe what part 99 
data you think should not be emission data and why (and whether such 
non-emission data should be considered confidential and why), and 
clearly explain how the suggested definition of ``emission data'' would 
be consistent with the ``necessary to determine'' clause in 40 CFR 
2.301, as well as with the purpose behind the statutory language.
    Individual determinations. The EPA is proposing confidentiality 
determinations by data element for the majority of the data elements in 
part 99. We are soliciting comment on whether there are data elements 
proposed to be included in 40 CFR 99.13(a) and (b) for which we should 
not finalize a confidentiality determination for the data element as 
not eligible for confidential treatment and instead make no 
determination for the data element, such that the confidentiality 
status of this data element would be evaluated on a case-by-case basis, 
in light of any publicly available information and in accordance with 
the existing CBI regulations in 40 CFR part 2, subpart B, upon receipt 
of a public request for these data elements. If respondents believe 
that EPA should not make a determination for a specific data element, 
please describe specifics of when a case-by-case determination would be 
necessary.
    Changes to determinations for subpart W throughputs. We request 
comment on the approach for the subpart W data elements specified in 
section IV.D. of this preamble. In particular, we request comment on no 
longer proposing a confidentiality determination for the quantity of 
residue gas leaving that has been processed by the facility and any gas 
that passes through the facility to sale without being processed by the 
facility in the calendar year, in thousand standard cubic feet, 
reported under proposed 40 CFR 98.236(aa)(3)(ix). We also request 
comment on the proposal to continue not making a confidentiality 
determination for the quantity of natural gas transported through a 
compressor station under 40 CFR 98.236(aa)(4)(i), as well as the 
criteria that should be used to conduct a case-by-case evaluation of 
the confidentiality of the data. We also request comment on whether 
these two data elements are customarily and actually treated as 
confidential, and if so, what approaches the EPA could use to treat the 
information as confidential while still making all emission data

[[Page 5360]]

publicly available, as required by CAA section 114(c).

V. Impacts of the Proposed Amendments

    In accordance with the requirements of Executive Order 12866, the 
EPA projected the emissions reductions, costs, benefits, and transfer 
payments that may result from this proposed action if finalized as 
proposed. These results are presented in detail in the Regulatory 
Impact Analysis of the Proposed Waste Emission Charge (RIA) 
accompanying this proposal developed in response to Executive Order 
12866 and available in the docket to this rulemaking, Docket ID No. 
EPA-HQ-OAR-2023-0434. This section provides a brief summary of the RIA.
    The WEC does not directly require emissions reductions from 
applicable facilities or emissions sources. However, by imposing a 
charge on methane emissions that exceed waste emissions thresholds, oil 
and natural gas facilities subject to the WEC are expected to perform 
methane mitigation actions and make operational changes where the costs 
of those changes are less than the WEC payments that could be avoided 
by reducing methane emissions. In addition, because VOC and HAP 
emissions are emitted along with methane from oil and natural gas 
industry activities, reductions in methane emissions as a result of the 
WEC also result in co-reductions of VOC and HAP emissions.
    The RIA accompanying this proposal analyzes emissions changes and 
economic impacts of the WEC that arise through two pathways: 1) through 
the application of cost-effective methane mitigation technologies, and 
2) through changes in oil and natural gas production and prices 
resulting from the WEC and associated mitigation responses. The 
analysis of methane mitigation is based on bottom-up engineering cost 
and mitigation potential information for a range of methane mitigation 
technologies. Application of methane mitigation technologies reduce WEC 
payments for WEC obligated parties by reducing methane emissions 
compared to a baseline without additional methane mitigation actions. 
The analysis assumes that methane mitigation is implemented where the 
engineering control costs are less than the avoided WEC payments for a 
particular mitigation technology.
    Additionally, oil and natural gas firms may change their production 
and operational decisions in response to the WEC. This potential impact 
is modeled using a partial equilibrium model of the crude oil and 
natural gas markets. The total cost of methane mitigation and WEC 
payments is added as an increase to production costs, resulting in 
changes in equilibrium production of oil and natural gas and associated 
emissions. Projected WEC payments are estimated after methane emissions 
reductions from both methane mitigation and economic impacts are 
accounted for.
    Using emissions reported to subpart W for RY2021 as an illustrative 
example, Table 1-1 of the RIA shows that the WEC would be imposed on 
less than 15 percent of national methane emissions from petroleum and 
natural gas systems. Total methane emissions reported to subpart W are 
significantly less than national methane emissions from the U.S. 
Greenhouse Gas Inventory. WEC-applicable facilities are the subset of 
GHGRP facilities that report at least 25,000 mt CO2e to 
subpart W industry segments subject to the WEC. It is also important to 
note that the WEC would only apply to methane emissions that are above 
the emissions threshold, not for all emissions from WEC-applicable 
facilities. The WEC has exemptions related to regulatory compliance, 
emissions from plugged wells, and unreasonable delay in environmental 
permitting, although these provisions do not impact the illustrative 
results in Table 1-1 of the RIA. Finally, emissions subject to WEC 
accounts for netting of emissions between facilities. Under the 
proposed WEC, facilities with emissions below their emissions threshold 
may reduce emissions subject to the WEC at other facilities with 
emissions above the emissions threshold where those facilities are 
under common ownership or control.
    The benefit-cost analysis contained in the RIA accompanying this 
rulemaking for the WEC considers the potential benefits and costs of 
the WEC arising from cost-effective mitigation actions under the WEC as 
well as the potential transfers from affected operators to the 
government in payments. Costs include engineering costs for methane 
mitigation actions and costs resulting from production changes in oil 
and gas energy markets under this rule. While the EPA expects a range 
of health and environmental benefits from reductions in methane, VOC, 
and HAP emissions under the WEC, the monetized benefits of the rule are 
limited to the estimated climate benefits from projected methane 
emissions reductions. These benefits are based on the social cost of 
greenhouse gases (SC-GHG). A screening-level analysis of ozone-related 
benefits from projected VOC reductions can be found in Appendix A of 
the RIA. However, these estimates are treated as illustrative and are 
not included in the quantified benefit-cost comparisons in the RIA.
    The EPA estimates that this action will result in cumulative 
emissions reductions of 960 thousand metric tons of methane over the 
2024 to 2035 period. These reductions represent about 33 percent of 
methane emissions that would be subject to the WEC before accounting 
for the adoption of cost-effective emission reduction technologies. 
Virtually all the reduced emissions result from mitigation activities 
undertaken by industry to reduce WEC payments. Less than one percent of 
reductions are associated with decreased production activity in the oil 
and gas sector resulting from the proposed rule. In addition to methane 
emissions reductions, the WEC is estimated to result in reductions of 
140 thousand metric tons of VOC and five thousand metric tons of HAP.
    The WEC has important interactions and is designed to work hand-in-
hand with the NSPS and EG for the Oil and Natural Gas Sector by 
accelerating the adoption of cost-effective methane mitigation 
technologies, including those that would eventually be required under 
the NSPS or EG. The annual projected emissions reductions, costs, and 
WEC obligations are significantly affected by these interactions.
    The EPA proposed updates to the Oil and Gas NSPS OOOOb/EG OOOOc in 
2021, published a supplemental proposal in 2022, and finalized in 
December 2023. In addition to requirements already in place, these 
rules include standards for many of the major sources of methane 
emissions in the oil and natural gas industry. To avoid double counting 
of benefits and costs, the baseline for this proposal includes 
reductions resulting from the NSPS OOOOb/EG OOOOc based on information 
from the 2023 Final RIA. Specifically, that analysis showed deep 
reductions in methane emissions beginning to take effect in 2028. As 
facilities implement emission controls required by the NSPS and EG, 
emissions subject to the WEC decline.
    The second interaction between the WEC and NSPS OOOOb/EG OOOOc is 
the regulatory compliance exemption provision of the WEC. Under this 
provision, when certain conditions are met with respect to the 
implementation of the Oil and Gas NSPS OOOOb/EG OOOOc, applicable 
facilities in compliance with their applicable methane emissions 
requirements are exempted from the WEC. The analysis in the RIA assumes 
that the regulatory compliance exemption takes effect in 2027, such 
that in 2027 and later,

[[Page 5361]]

facilities in the industry segments subject to requirements under the 
NSPS OOOOb/EG OOOOc do not owe WEC payments.
    Climate benefits associated with this proposed rule are the 
monetized value of GHG reductions using the SC-GHG, which calculates 
the avoided climate related damages from reducing GHG emissions. 
Methane is the principal component of natural gas. As discussed in 
section I.C.1. of this preamble, methane is also a potent GHG that, 
once emitted into the atmosphere, absorbs terrestrial infrared 
radiation, which in turn contributes to increased global warming and 
continuing climate change.
    This proposed rulemaking is projected to reduce VOC emissions, 
which are a precursor to ozone. Ozone is not generally emitted directly 
into the atmosphere but is created when its two primary precursors, VOC 
and oxides of nitrogen (NOX), react in the atmosphere in the 
presence of sunlight. Emissions reductions under the WEC may decrease 
ozone formation, human exposure to ozone, and the incidence of ozone-
related health effects. VOC emissions are also a precursor to 
PM2.5, so VOC reductions may also decrease human exposure to 
PM2.5 and the incidence of PM2.5- related health 
effects.
    Available emissions data show that several different HAP are 
emitted from oil and natural gas operations. Emissions of eight HAP 
make up a large percentage of the total HAP emissions by mass from the 
oil and natural gas sector: toluene, hexane, benzene, xylenes (mixed), 
ethylene glycol, methanol, ethyl benzene, and 2,2,4- 
trimethylpentane.\44\ Reductions of HAP emissions under the WEC may 
reduce exposure to these and other HAP.
---------------------------------------------------------------------------

    \44\ U.S. EPA. The Benefits and Costs of the Clean Air Act from 
1990 to 2020. Washington, DC. Retrieved from https://www.epa.gov/sites/production/files/2015-07/documents/fullreport_rev_a.pdf.
---------------------------------------------------------------------------

    In section 9.3 of the RIA, the EPA identifies existing potential 
environmental justice issues for the communities in counties that have 
emissions sources that are expected to owe the WEC charge before 
accounting for mitigation actions and thus may be positively affected 
by emissions changes under the proposal. Compared to the national 
average, these communities include a higher percentage of individuals 
who identify as racial and ethnic minorities, have lower average 
incomes, and have slightly elevated health risks associated with 
various air emissions. Reductions in VOC and HAP emissions as a result 
of the WEC are expected to benefit communities in these counties. 
Because the WEC does not directly require emissions reductions, the EPA 
has not projected specific locations where emissions reductions might 
occur. In addition, detailed proximity analysis is infeasible because 
the emissions affected by the WEC occur at hundreds of thousands of 
locations.
    The total cost of the proposed rule includes the engineering costs 
for methane mitigation actions implemented by the oil and natural gas 
industry in order to avoid or reduce WEC obligations. This includes the 
initial capital costs required to implement and install the specific 
mitigation technology. In addition, for mitigation technologies with 
expected lifetimes greater than one-year, annual recurring operations 
and maintenance costs, which include labor, energy and materials, are 
also incorporated. Finally, the total mitigation costs also include the 
avoided cost of natural gas losses.
    The social cost of energy market impacts is the loss in consumer 
and producer surplus value from changes in natural gas market 
production and prices. The economic impacts analysis uses a partial 
equilibrium model and estimates that the impact of the gas market is 
minimal, with the largest impact occurring in the first few years with 
a price increase of less than 0.1 percent and a quantity reduction of 
less than 0.1 percent.
    Table 5 presents results of the benefit-cost analysis for the 
proposed WEC. It presents the present value (PV) and equivalent annual 
value (EAV), estimated using discount rates of 2, 3, and 7 percent, of 
the changes in quantified benefits, costs, and net benefits relative to 
the baseline.\45\ These values reflect an analytical time horizon of 
2024 to 2035, are discounted to 2023, and are presented in 2019 
constant dollars. The table includes consideration of the non-monetized 
benefits associated with the emissions reductions projected under this 
proposal.
---------------------------------------------------------------------------

    \45\ Monetized climate effects are presented under a 2 percent 
near-term Ramsey discount rate, consistent with EPA's updated 
estimates of the SC-GHG. The 2003 version of OMB's Circular A-4 had 
generally recommended 3 percent and 7 percent as default discount 
rates for costs and benefits, though as part of the Interagency 
Working Group on the Social Cost of Greenhouse Gases, OMB had also 
long recognized that climate effects should be discounted only at 
appropriate consumption-based discount rates. OMB finalized an 
update to Circular A-4 in 2023, in which it recommended the general 
application of a 2.0 percent discount rate to costs and benefits 
(subject to regular updates), as well as the consideration of the 
shadow price of capital when costs or benefits are likely to accrue 
to capital. Because the SC-GHG estimates reflect net climate change 
damages in terms of reduced consumption (or monetary consumption 
equivalents), the use of the discount rate estimated using the 
average return on capital (7 percent in OMB Circular A-4 (2003)) to 
discount damages estimated in terms of reduced consumption would 
inappropriately underestimate the impacts of climate change for the 
purposes of estimating the SC-GHG. See section 6.1 of the RIA for 
more discussion.

     Table 4--Projected Emissions Reductions Under the Proposed Rule
                            [2024-2035 Total]
------------------------------------------------------------------------
                                                             Emissions
                                                            reductions
                        Pollutant                           (2024-2035
                                                              Total)
------------------------------------------------------------------------
Methane (thousand metric tons) \a\......................             960
VOC (thousand metric tons)..............................             140
Hazardous Air Pollutant (thousand short tons)...........               5
Methane (million metric tons CO2e) \b\..................              27
------------------------------------------------------------------------
\a\ To convert from metric tons to short tons, multiply the short tons
  by 1.102. Alternatively, to convert from short tons to metric tons,
  multiply the short tons by 0.907.
\b\ Carbon dioxide equivalent (CO2e). Calculated using a global warming
  potential of 28.


[[Page 5362]]


                                   Table 5--Benefits, Costs, and Net Benefits of the Proposed Rule, 2024 Through 2035
                                                   [Dollar estimates in millions of 2019 dollars] \a\
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                     2 percent near-term Ramsey discount rate
                                                         -----------------------------------------------------------------------------------------------
                                                                            Equivalent                      Equivalent                      Equivalent
                                                           Present value   annual value    Present value   annual value    Present value   annual value
--------------------------------------------------------------------------------------------------------------------------------------------------------
Climate Benefits \b\....................................          $1,900            $180          $1,900            $180          $1,900            $180
                                                         -----------------------------------------------------------------------------------------------
                                                              2 percent discount rate
                                                              3 percent discount rate
                                                              7 Percent discount rate
                                                         -----------------------------------------------------------------------------------------------
                                                           Present value      Equivalent   Present value      Equivalent   Present value      Equivalent
                                                                            annual value                    annual value                    annual value
                                                         -----------------------------------------------------------------------------------------------
Total Social Costs......................................            $390             $37            $380             $38            $340             $43
                                                         -----------------------------------------------------------------------------------------------
Cost of Methane Mitigation..............................            $360             $34            $350             $35            $320             $40
                                                         -----------------------------------------------------------------------------------------------
Cost of Energy Market Impacts...........................             $30              $3             $29              $3             $26              $3
                                                         -----------------------------------------------------------------------------------------------
Net Benefits............................................          $1,500            $140          $1,500            $140          $1,600            $140
                                                         -----------------------------------------------------------------------------------------------
Non-Monetized Benefits..................................  Climate and ozone health benefits from reducing 960 thousand metric tons of methane from 2024
                                                          to 2035.
                                                          PM2.5 and ozone health benefits from reducing 140 thousand metric tons of VOC from 2024 to
                                                          2035.\c\
                                                          HAP benefits from reducing 5 thousand metric tons of HAP from 2024 to 2035.
                                                          Visibility benefits.
                                                          Reduced vegetation effects.
--------------------------------------------------------------------------------------------------------------------------------------------------------
\a\ Values rounded to two significant figures. Totals may not appear to add correctly due to rounding.
\b\ Climate benefits are based on reductions in methane emissions and are calculated using three different estimates of the social cost of methane (SC-
  CH4) (under 1.5 percent, 2.0 percent, and 2.5 percent near-term Ramsey discount rates). For the presentational purposes of this table, we show the
  climate benefits associated with the SC-CH4 at the 2 percent near-term Ramsey discount rate. Please see Table 6-5 of the RIA for the full range of
  monetized climate benefits estimates.
\c\ A screening-level analysis of ozone benefits from VOC reductions can be found in Appendix A of the RIA.

    WEC payments are transfers and do not affect total net benefits to 
society as a whole because payments by oil and natural gas operators 
are offset by receipts by the government. Therefore, from a net-benefit 
accounting perspective, transfers are considered separately from costs 
and benefits (and are therefore not included in Table 5). As explained 
further in section 2.7 of the RIA, the approach taken here is in line 
with OMB guidance and the approach taken for RIAs for other rules 
impacting payments to the government, such as the Bureau of Land 
Management (BLM)'s waste prevention rule.
    One of the reasons that transfers are not considered costs is 
because they represent payments to the U.S. Treasury that do not affect 
total resources available to society. Payments to the U.S. Treasury can 
then be used to fund other programs, and the pairing of revenue 
collection (e.g., the WEC payments) with commensurate expenditures 
(e.g., financial assistance programs) by the federal government can be 
designed to be revenue neutral. The Methane Emission Reduction Program 
created under CAA section 136 includes both collection and expenditure 
components. In addition to establishing the WEC, another key purpose of 
CAA section 136 is to encourage the development of innovative 
technologies in the detection and mitigation of methane emissions. See 
168 Cong. Rec. E869 (August 23, 2022) (statement of Rep. Frank 
Pallone). CAA section 136(a) and (b) provides $1.55 billion to, among 
other things, help finance the early adoption of emissions reduction 
methodologies and technologies and to support monitoring of methane 
emissions. These incentives for methane mitigation and monitoring 
complement the WEC.
    The WEC has the effect of better aligning the economic incentives 
of oil and natural gas companies with the costs and benefits faced by 
society from oil and gas activities. In the baseline scenario the 
environmental damages resulting from methane emissions from the oil and 
gas sector are a negative externality spread across society as a whole. 
Under the WEC, this negative externality is internalized, oil and gas 
companies are required to make WEC payments in proportion to the 
climate damages of methane emissions subject to the WEC. Alternatively, 
firms can avoid making WEC payments by mitigating their emissions 
generating climate benefits associated with the amount of mitigation.
    Table 6 provides details of the calculation steps used to estimate 
projected WEC obligations and climate damages based on projected 
emission subject to WEC. In order to compare projected WEC payments to 
climate damages from emissions subject to the WEC, WEC payments are 
converted from nominal dollars to 2019 constant dollars using a chain-
weighted GDP price index from the 2023 Annual Energy Outlook. Projected 
WEC payments after accounting for methane mitigation and energy market 
impacts are estimated to be about $750 million nominal dollars in 2024, 
and then drop significantly as the regulatory compliance exemption 
takes effect in 2027.

[[Page 5363]]



                                   Table 6--Benefits, Costs, and Net Benefits of the Proposed Rule, 2024 Through 2035
                                                   [Dollar Estimates in Millions of 2019 Dollars] \a\
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                             Methane
                                        emissions subject   Charge specified   WEC payments in                       SC-CH4 Values at   Climate damages
                                         to WEC in policy     by Congress      policy scenario    WEC payments in    2% discount rate    from emissions
                 Year                        scenario        (nominal $ per    (million nominal   policy scenario   (2019$ per metric    subject to WEC
                                         (thousand metric     metric ton)             $)          (million 2019$)          ton)         (million 2019$)
                                              tons)                                                                                           \a\
--------------------------------------------------------------------------------------------------------------------------------------------------------
2024..................................                830               $900               $750               $620             $1,900             $1,600
2025..................................                650              1,200                770                630              2,000              1,300
2026..................................                430              1,500                640                510              2,100                890
2027..................................                  9              1,500                 13                 10              2,200                 18
2028..................................                  9              1,500                 13                 10              2,200                 19
2029..................................                  9              1,500                 13                 10              2,300                 20
2030..................................                  9              1,500                 13                  9              2,400                 20
2031..................................                  9              1,500                 13                  9              2,500                 21
2032..................................                  9              1,500                 13                  9              2,500                 21
2033..................................                  8              1,500                 13                  9              2,600                 21
2034..................................                  8              1,500                 13                  8              2,700                 21
2035..................................                  8              1,500                 13                  8              2,800                 21
                                       -----------------------------------------------------------------------------------------------------------------
    Total 2024-2035...................              2,000  .................              2,300              1,800  .................              4,000
--------------------------------------------------------------------------------------------------------------------------------------------------------
\a\ Climate damages are based on remaining methane emissions subject to WEC after accounting for emissions reductions and are calculated using three
  different estimates of the social cost of methane (SC-CH4) (under 1.5 percent, 2.0 percent, and 2.5 percent near-term Ramsey discount rates). For the
  presentational purposes of this table, we show the climate benefits associated with the SC-CH4 at the 2 percent near-term Ramsey discount rate.

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 14094: Modernizing Regulatory Review

    This action is a ``significant regulatory action'' as defined under 
section 3(f)(1) of Executive Order 12866, as amended by Executive Order 
14094. Accordingly, the EPA submitted this action to the Office of 
Management and Budget (OMB) for Executive Order 12866 review. 
Documentation of any changes made in response to the Executive Order 
12866 review is available in the docket for this rulemaking, Docket ID 
No. EPA-HQ-OAR-2023-0434. The EPA prepared an analysis of the potential 
impacts associated with this action. This analysis, Regulatory Impact 
Analysis of the Proposed Waste Emission Charge, is also available in 
the docket to this rulemaking and is briefly summarized in section V. 
of this preamble.

B. Paperwork Reduction Act (PRA)

    The information collection activities in this proposed rule have 
been submitted for approval to the OMB under the PRA. The Information 
Collection Request (ICR) document that the EPA prepared has been 
assigned EPA ICR number 2787.01. You can find a copy of the ICR in the 
docket for this rule, Docket ID No. EPA-HQ-OAR-2023-0434, and it is 
briefly summarized here.
    The EPA estimates that the proposed rule would result in an 
increase in burden. The burden associated with the proposed rule is due 
to reporting and recordkeeping requirements in the proposed rule.
    The respondent reporting burden for this collection of information 
is estimated to be an annual average of 12,799 hours and $1,700,304 
over the 3 years covered by this information collection, which includes 
an annual average of $1,669,752 in labor costs, $0 in operation and 
maintenance costs, and $30,552 in capital costs. The annual average 
incremental burden to the EPA for this period is anticipated at 31,200 
hours and $5,670,955 ($2023) over the 3 years covered by this 
information collection, which includes an annual average of $2,004,288 
in labor costs and $3,666,667 in non-labor costs.
    Respondents/affected entities: Owners and operators of petroleum 
and natural gas systems that must submit a WEC filing to the EPA to 
comply with proposed 40 CFR part 99.
    Respondent's obligation to respond: The respondent's obligation to 
respond is mandatory under the authority provided in CAA sections 114 
and 136.
    Estimated number of respondents: 536.
    Frequency of response: Annually.
    Total estimated burden: 12,799 hours (per year). Burden is defined 
at 5 CFR 1320.3(b).
    Total estimated cost: $1.7 million (per year), includes $30,552 
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.
    Submit your comments on the Agency's need for this information, the 
accuracy of the provided burden estimates and any suggested methods for 
minimizing respondent burden to the EPA using the docket identified at 
the beginning of this rule. You may also send your ICR-related comments 
to OMB's Office of Information and Regulatory Affairs using the 
interface at https://www.reginfo.gov/public/do/PRAMain. Find this 
particular information collection by selecting ``Currently under 
Review--Open for Public Comments'' or by using the search function. OMB 
must receive comments no later than February 26, 2024. The EPA will 
respond to any ICR-related comments in the final rule.

C. Regulatory Flexibility Act (RFA)

    I certify that this proposed action would not have a significant 
economic impact on a substantial number of small entities under the 
RFA. The small entities that would be subject to the proposed 
requirements of this action are small businesses in the petroleum and 
natural gas industry. Small entities include small businesses, small 
organizations, and small governmental jurisdictions. The EPA has 
determined that some small entities are affected because their 
processes emit methane that must be reported under subpart W and thus 
may be subject to WEC.
    To evaluate whether this proposed rule would have a significant 
economic impact on a substantial number of small entities, the EPA 
conducted a small entity analysis that evaluated the costs of the 
proposed rule on small entities

[[Page 5364]]

identified in the reporting year (RY) 2021 subpart W dataset. The EPA 
used reported facility-to-parent company and facility-to-owner or 
operator data to link facilities to WEC obligated parties. The EPA then 
reviewed the available RY 2021 data for the WEC obligated parties of 
subpart W facilities to determine whether the reporters were part of a 
small entity and whether the annualized costs of the proposal would 
have a significant impact on a substantial number of small entities. 
The number of small entities potentially affected by the proposed WEC 
regulation were estimated based on the information collected for 472 
WEC obligated parties. Of these, 439 were identified as small entities. 
Although the screening analysis suggests that some small entities may 
have cost-to-revenue ratios that exceed 3 percent (approximately 17 
percent), the EPA's evaluation of the impacts to small entities relied 
on several methodologies involving conservative assumptions. For 
example, the identification and classification of subpart W parent 
entities reporting under more than one NAICS code resulted in a 
designation of ``small'' based on whether the business information 
available met the SBA size classification threshold for a single NAICS 
code. In addition to the conservative assumptions, there were further 
mitigating factors not included in the screening analysis that would 
likely significantly reduce compliance costs, and, as a result, cost-
to-revenue-ratios. For example, the compliance cost estimate used only 
the defined WEC cost and did not account for early adoption of 
mitigation measures that could lower an entity's emissions below the 
threshold and therefore result in no WEC charge. Details of this 
analysis are presented in the Regulatory Impact Analysis of the 
Proposed Waste Emissions Charge, available in the docket for this 
rulemaking. The cumulative effect of the mitigating factors and 
conservative assumptions used in the screening analysis indicates that, 
overall, the proposed rule would not likely have a significant impact 
on a substantial number of small entities.

D. Unfunded Mandates Reform Act (UMRA)

    This action contains a federal mandate under UMRA, 2 U.S.C. 1531-
1538, that may result in expenditures of $100 million or more for 
state, local and tribal governments, in the aggregate, or the private 
sector in any one year. Accordingly, the EPA has prepared under section 
202 of the UMRA a written statement of the benefit-cost analysis, which 
can be found in Section V of this preamble and in the Regulatory Impact 
Analysis of the Proposed Waste Emissions Charge (RIA), available in the 
docket for this rulemaking. The proposed action in part implements 
mandate(s) specifically and explicitly set forth in CAA section 136.
    The applicability, magnitude of charge, methane emissions subject 
to charge, and exemptions from charge for the WEC program are 
established by CAA section 136(c) through (g). Given that this 
framework is required by statute, it is not possible for EPA to 
consider regulatory alternatives that are inconsistent with these 
elements. As such, to evaluate the benefits and costs of the proposed 
rule, in the RIA accompanying this rulemaking two scenarios were 
evaluated: a baseline scenario (i.e., not including the effects of the 
WEC program) and a policy scenario inclusive of the costs, benefits, 
and transfers projected under the proposed rule. This action is not 
subject to the requirements of section 203 of UMRA because it contains 
no regulatory requirements that might significantly or uniquely affect 
small governments. This proposed rule does not apply to governmental 
entities unless the government entity owns a facility in the applicable 
petroleum and gas industry segments and reports more 25,000 mt 
CO2e to subpart W of the GHGRP. It would not impose any 
implementation responsibilities on state, local, or tribal governments 
and it is not expected to increase the cost of existing regulatory 
programs managed by those governments. Thus, the impact on governments 
affected by the proposed rule is expected to be minimal.
    However, consistent with the EPA's policy to promote communications 
between the EPA and state and local governments, the EPA sought 
comments from small governments concerning the regulatory requirements 
that might significantly or uniquely affect them in the development of 
this proposed rule. Specifically, the EPA previously published a 
Request for Information (RFI) seeking public comment in a non-
regulatory docket to collect responses to a range of questions related 
to the Methane Emissions Reduction Program, including related to 
implementation of the WEC (see Docket ID No. EPA-HQ-OAR-2022-0875). The 
EPA received five comments from government entities related to 
implementation of the WEC; these comments were considered during the 
development of the proposed rule. The EPA continues to be interested in 
the potential impacts of the proposed rule amendments on state, local, 
or tribal governments and welcomes comments on issues related to such 
impacts.

E. 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. This 
proposed rule will not apply to governmental entities unless the 
government entity owns a facility in the applicable petroleum and gas 
industry segments that and reports more 25,000 mt CO2e to 
subpart W of the GHGRP. Therefore, the EPA anticipates relatively few 
state or local government facilities will be affected. However, 
consistent with the EPA's policy to promote communications between EPA 
and state and local governments, the EPA specifically solicits comment 
on this proposed action from state and local officials.

F. Executive Order 13175: Consultation and Coordination With Indian 
Tribal Governments

    This action has tribal implications. However, it will neither 
impose substantial direct compliance costs on federally recognized 
tribal governments, nor preempt tribal law. This proposed regulation 
will apply directly to petroleum and natural gas facilities that may be 
owned by tribal governments. However, it will generally only have 
tribal implications where the tribal entity owns a facility in an 
applicable industry segment that emits GHGs above threshold levels; 
therefore, relatively few tribal facilities will be affected. Of the 
subpart W facilities currently reporting to the GHGRP in RY2021, we 
identified four facilities currently reporting to part 98, subpart W 
that are owned or partially owned by one tribal parent company. Based 
on RY2021 data, all four facilities would be WEC applicable facilities, 
and the WEC applicable emissions (without consideration of exemptions) 
for the individual facilities would range from less than 0 mt 
CH4 for one facility, up to about 3,500 mt CH4 
for the largest facility (which corresponds to a WEC obligation of $3.1 
million). Note that one of the facilities is within the onshore natural 
gas processing sector, and thus, this calculation utilizes proxy data 
of CBI throughput, which may not reflect the actual facility throughput 
and resulting WEC applicable emissions. Each of the four facilities has 
a different owner or operator or combination of owners or operators, so 
the tribe likely

[[Page 5365]]

would not be the WEC obligated party for all four facilities. These 
estimates do not consider any exemptions that might apply for the three 
facilities with emissions greater than the facility waste emissions 
threshold.
    In addition to tribes that would be directly impacted by the WEC 
due to owning a facility subject to the charge, the EPA anticipates 
that tribes could be impacted in cases where facilities subject to the 
charge are located in Indian country. For example, the EPA reviewed the 
location of the production wells reported by facilities under the 
Onshore Petroleum and Natural Gas Production industry segment and found 
production wells reported under subpart W on lands associated with 
approximately 20 tribes. Therefore, although the EPA anticipates that 
at most only one tribe may be designated as a WEC obligated party and 
has the potential to be subject to the WEC, the EPA has sought 
opportunities to provide information to tribal governments and 
representatives during rule development. On November 4, 2022, the EPA 
published an RFI seeking public comment on a range of questions related 
to the Methane Emissions Reduction Program, including implementation of 
the WEC (see Docket ID No. EPA-HQ-OAR-2022-0875). Further, consistent 
with the EPA Policy on Consultation and Coordination with Indian 
Tribes, the EPA specifically solicits comment on this proposed action 
from Tribal officials. The EPA will engage in consultation with Tribal 
officials during the development of this action.

G. Executive Order 13045: Protection of Children From Environmental 
Health Risks and Safety Risks

    The EPA interprets Executive Order 13045 as applying only to 
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 proposed action would not 
establish an environmental standard intended to mitigate health or 
safety risks and does not focus on information-gathering actions 
concerned with children's health. Therefore, this proposed action is 
not subject to Executive Order 13045. For the same reasons, the EPA's 
Policy on Children's Health also does not apply.
    Although this proposed action does not establish an environmental 
standard applicable to methane emissions or mandate methane emissions 
reductions, it is expected that the WEC implemented under this proposed 
action would result in elective methane mitigation actions by 
applicable facilities in the oil and gas industry in order to reduce, 
or eliminate, the imposition of charges. As such, the EPA believes that 
the impacts of this proposed action would result in a reduction in an 
environmental health or safety risk that has a disproportionate effect 
on children. Accordingly, the Agency has elected to evaluate the 
environmental health and welfare effects of climate change on children. 
Greenhouse gases, including methane, contribute to climate change and 
are emitted in significant quantities by the oil and gas industry. The 
EPA believes that the implementation of the WEC in this action, if 
finalized, would improve children's health as a result of methane 
mitigation actions and operational changes taken by oil and gas 
applicable facilities to avoid the imposition of WEC. The assessment 
literature cited in the EPA's 2009 Endangerment Findings concluded that 
certain populations and life stages, including children, the elderly, 
and the poor, are most vulnerable to climate-related health effects (74 
FR 66524, December 15, 2009). The assessment literature since 2009 
strengthens these conclusions by providing more detailed findings 
regarding these groups' vulnerabilities and the projected impacts they 
may experience (e.g., the 2016 Climate and Health Assessment).\46\ 
These assessments describe how children's unique physiological and 
developmental factors contribute to making them particularly vulnerable 
to climate change. Impacts to children are expected from heat waves, 
air pollution, infectious and waterborne illnesses resulting in 
physical and mental health effects from extreme weather events. In 
addition, children are among those especially susceptible to most 
allergic diseases, as well as health effects associated with storms and 
floods. Additional health concerns may arise in low-income households, 
especially those with children, if climate change reduces food 
availability and increases prices, leading to food insecurity within 
households.
---------------------------------------------------------------------------

    \46\ USGCRP, 2016: The Impacts of Climate Change on Human Health 
in the United States: A Scientific Assessment. Crimmins, A., J. 
Balbus, J.L. Gamble, C.B. Beard, J.E. Bell, D. Dodgen, R.J. Eisen, 
N. Fann, M.D. Hawkins, S.C. Herring, L. Jantarasami, D.M. Mills, S. 
Saha, M.C. Sarofim, J. Trtanj, and L. Ziska, Eds. U.S. Global Change 
Research Program, Washington, DC, 312 pp. https://dx.doi.org/10.7930/J0R49NQX.
---------------------------------------------------------------------------

H. Executive Order 13211: Actions That Significantly Affect Energy 
Supply, Distribution, or Use

    This proposed action is not a ``significant energy action'' because 
it is not likely to have a significant adverse effect on the supply, 
distribution or use of energy. To make this determination, we compare 
the projected change in crude oil and natural gas costs and production 
to guidance articulated in a January 13, 2021 OMB memorandum 
``Furthering Compliance with Executive Order 13211, Titled `Actions 
Concerning Regulations That Significantly Affect Energy Supply, 
Distribution, or Use.' '' \47\ With respect to increases in the cost of 
energy production or distribution, the guidance indicates that a 
regulatory action produces a significant adverse effect if it is 
expected to increase costs in excess of one percent. With respect to 
crude oil production, the guidance indicates that a regulatory action 
produces a significant adverse effect if it is expected to produce 
reductions in crude oil supply, in excess of 20 million barrels per 
year. With respect to natural gas production, the guidance indicates 
that a regulatory action produces a significant adverse effect if it 
reduces natural gas production in excess of 40 million thousand cubic 
feet (mcf) per year.\48\ The economic impacts analysis conducted as 
part of the RIA accompanying this rulemaking estimated a maximum impact 
on the gas market of a 0.05 percent price increase and a 0.03 percent 
decrease in production. The highest impact year is estimated to be in 
2026, with a production decrease of 10.7 million mcf of natural gas. 
The analysis projected a maximum impact on the oil market of 0.04 
percent price increase and a 0.03 percent decrease in production. The 
highest impact year is estimated to be in 2026, with an estimated 
production decrease of 1.27 million barrels of oil. These impacts are 
substantially below the thresholds available in OMB memoranda as 
measures of a significant adverse effect on the energy supply. Further 
discussion of this analysis is available in the Regulatory Impact 
Analysis of the Proposed Waste

[[Page 5366]]

Emissions Charge, available in the docket for this rulemaking.
---------------------------------------------------------------------------

    \47\ See https://www.whitehouse.gov/wp-content/uploads/2021/01/M-21-12.pdf.
    \48\ The 2021 E.O. 13211 guidance memo states that the natural 
gas production decrease that indicates the regulatory action is a 
significant energy action is 40 mcf per year. Because this is a 
relatively small amount of natural gas and previous guidance from 
2001 indicated a threshold of 25 million Mcf, we assume the 2021 
memo was intended to establish 40 million mcf as the indicator of an 
adverse energy effect. See https://www.whitehouse.gov/wp-content/uploads/2017/11/2001-M-01-27-Guidance-for-Implementing-E.O.-13211.pdf.
---------------------------------------------------------------------------

I. National Technology Transfer and Advancement Act

    This rulemaking does not involve technical standards.

J. Executive Order 12898: Federal Actions To Address Environmental 
Justice in Minority Populations and Low-Income Populations and 
Executive Order 14096: Revitalizing Our Nation's Commitment to 
Environmental Justice for All

    The EPA believes that the emissions reductions likely to result 
from this rule will improve health and environmental outcomes for 
communities facing disproportionate and adverse human health effects 
from the pollution subject to the waste emissions charge, including 
environmental justice communities. The EPA proposes, however, to 
determine that Executive Order 12898 does not apply to this rulemaking 
because it is a rule that addresses information collection, reporting 
procedures, and imposition of the waste emission charge directive of 
CAA section 136. Although the EPA anticipates a reduction in methane 
and associated co-pollutant emissions from this action, if finalized, 
these reductions are not the result of emissions standards or mandated 
reductions.
    Although this regulation does not require action that will directly 
affect human health or environmental conditions, the EPA has identified 
and addressed environmental justice concerns by electing to conduct a 
qualitative assessment of the environmental justice outcomes from the 
proposed action. The EPA believes the human health or environmental 
conditions that exist prior to this proposed action would result in or 
have the potential to result in disproportionate and adverse human 
health or environmental effects on people of color, low-income 
populations, and/or Indigenous peoples. The EPA identified 563 counties 
where Onshore Petroleum and Natural Gas Production and/or Onshore 
Petroleum and Natural Gas Gathering and Boosting facilities with 
emissions that may be above the waste emissions threshold and therefore 
subject to the WEC operated in 2021. These are the counties where 
emissions might change due to the WEC. The EPA found that there are 
generally higher percentages of low income and members of minority 
groups in these communities who may experience higher than average 
health risks. The EPA believes that in aggregate the proposed action 
will result in reduction of methane, hazardous air pollutants, and 
volatile organic compounds, and, generally, this result will improve 
environmental justice outcomes.
    The information supporting this Executive Order review is contained 
in the Regulatory Impact Analysis of the Proposed Waste Emissions 
Charge, available in the docket for this rulemaking.

K. Determination Under CAA Section 307(d)

    Pursuant to CAA section 307(d)(1)(V), the Administrator determines 
that this proposed action is subject to the provisions of CAA section 
307(d). Section 307(d)(1)(V) of the CAA provides that the provisions of 
CAA section 307(d) apply to ``such other actions as the Administrator 
may determine.''

List of Subjects

40 CFR Part 2

    Administrative practice and procedure, Confidential business 
information, Courts, Environmental protection, Freedom of information, 
Government employees.

40 CFR Part 99

    Environmental protection, Greenhouse gases, Natural gas, Petroleum, 
Reporting and recordkeeping requirements, Penalties.

Michael S. Regan,
Administrator.
    For the reasons stated in the preamble, the Environmental 
Protection Agency proposes to amend title 40, chapter I, of the Code of 
Federal Regulations as follows:

PART 2--PUBLIC INFORMATION

0
1. The authority citation for part 2 continues to read as follows:

    Authority: 5 U.S.C. 552, 552a, 553; 28 U.S.C. 509, 510, 534; 31 
U.S.C. 3717.

Subpart B--Confidentiality of Business Information

0
2. Amend Sec.  2.301 by revising paragraph (d) to read as follows:


Sec.  2.301  Special rules governing certain information obtained under 
the Clean Air Act.

* * * * *
    (d) Data submitted under part 98 or part 99 of this chapter--(1) 
Sections 2.201 through 2.215 do not apply to data submitted under part 
98 or part 99 of this chapter that EPA has determined, pursuant to 
sections 114(c) and 307(d) of the Clean Air Act, to be either of the 
following:
    (i) Emission data.
    (ii) Data not otherwise entitled to confidential treatment pursuant 
to section 114(c) of the Clean Air Act.
    (2) Except as otherwise provided in this paragraph (d)(2) and 
paragraph (d)(4) of this section, Sec. Sec.  2.201 through 2.215 do not 
apply to data submitted under part 98 or part 99 of this chapter that 
EPA has determined, pursuant to sections 114(c) and 307(d) of the Clean 
Air Act, to be entitled to confidential treatment. EPA shall treat that 
information as confidential in accordance with the provisions of Sec.  
2.211, subject to paragraph (d)(4) of this section and Sec.  2.209.
    (3) Upon receiving a request under 5 U.S.C. 552 for data submitted 
under part 98 or part 99 of this chapter that EPA has determined, 
pursuant to sections 114(c) and 307(d) of the Clean Air Act, to be 
entitled to confidential treatment, the EPA office shall furnish the 
requestor a notice that the information has been determined to be 
entitled to confidential treatment and that the request is therefore 
denied. The notice shall include or cite to the appropriate EPA 
determination.
    (4) Modification of prior confidentiality determination. A 
determination made pursuant to sections 114(c) and 307(d) of the Clean 
Air Act that information submitted under part 98 or part 99 of this 
chapter is entitled to confidential treatment shall continue in effect 
unless, subsequent to the confidentiality determination, EPA takes one 
of the following actions:
    (i) EPA determines, pursuant to sections 114(c) and 307(d) of the 
Clean Air Act, that the information is emission data or data not 
otherwise entitled to confidential treatment under section 114(c) of 
the Clean Air Act.
    (ii) The Office of General Counsel issues a final determination, 
based on the criteria in Sec.  2.208, stating that the information is 
no longer entitled to confidential treatment because of change in the 
applicable law or newly-discovered or changed facts. Prior to making 
such final determination, EPA shall afford the business an opportunity 
to submit comments on pertinent issues in the manner described by 
Sec. Sec.  2.204(e) and 2.205(b). If, after consideration of any timely 
comments submitted by the business, the Office of General Counsel makes 
a revised final determination that the information is not entitled to 
confidential treatment under section 114(c) of the Clean Air Act, EPA 
will notify the business in accordance with

[[Page 5367]]

the procedures described in Sec.  2.205(f)(2).
* * * * *
0
3. Add part 99 to read as follows:

PART 99--WASTE EMISSIONS CHARGE

Sec.
Subpart A--General Provisions
99.1 Purpose and scope.
99.2 Definitions.
99.3 Who must file?
99.4 How do I authorize and what are the responsibilities of the 
designated representative?
99.5 When must I file and remit the applicable WEC obligation?
99.6 How do I file?
99.7 What are the general reporting, recordkeeping, and verification 
requirements of this part?
99.8 What are the general provisions for assessment of the WEC 
obligation?
99.9 How are payments required by this part made?
99.10 What fees apply to delinquent payments?
99.11 What are the compliance and enforcement provisions of this 
part?
99.12 What addresses apply for this part?
99.13 What are the confidentiality determinations and related 
procedures for this part?
Subpart B--Determining Waste Emissions Charge
99.20 How will the waste emissions threshold for each WEC applicable 
facility be determined?
99.21 How will the WEC applicable emissions for a WEC applicable 
facility be determined?
99.22 How will the net WEC emissions for a WEC obligated party be 
determined?
99.23 How will the WEC Obligation for a WEC obligated party be 
determined?
Subpart C--Unreasonable Delay Exemption
99.30 Which facilities qualify for the exemption for emissions 
caused by an unreasonable delay in environmental permitting of 
gathering or transmission infrastructure?
99.31 What are the reporting requirements for the exemption for 
emissions caused by an unreasonable delay in environmental 
permitting of gathering or transmission infrastructure?
99.32 How are the methane emissions caused by an unreasonable delay 
in environmental permitting of gathering or transmission 
infrastructure quantified?
99.33 What are the recordkeeping requirements for methane emissions 
caused by an unreasonable delay in environmental permitting of 
gathering or transmission infrastructure?
Subpart D--Regulatory Compliance Exemption
99.40 When does the regulatory compliance exemption come into 
effect, and under what conditions does the exemption cease to be in 
effect?
99.41 Which facilities qualify for the exemption for regulatory 
compliance?
99.42 What are the reporting requirements for the exemption for 
regulatory compliance?
Subpart E--Exemption for Permanently Shut-in and Plugged Wells
99.50 Which facilities qualify for the exemption of emissions from 
permanently shut-in and plugged wells?
99.51 What are the reporting requirements for the exemption for 
wells that were permanently shut-in and plugged?
99.52 How are the net emissions attributable to all wells at a WEC 
applicable facility that were permanently shut-in and plugged in the 
reporting year quantified?

    Authority:  42 U.S.C. 7401-7671q; 31 U.S.C. 3717.

Subpart A--General Provisions


Sec.  99.1  Purpose and scope.

    (a) This part establishes requirements for owners and operators of 
certain petroleum and natural gas systems facilities to make filings 
and be assessed waste emission charges as required by section 136 of 
the Clean Air Act.
    (b) Owners and operators of facilities that are subject to this 
part must follow the requirements of this subpart and all applicable 
subparts of this part. If a conflict exists between a provision in 
subpart A and any other applicable subpart, the requirements of the 
applicable subpart shall take precedence.


Sec.  99.2  Definitions.

    All terms used in this part shall have the same meaning given in 
the Clean Air Act, unless as defined in this section. Terms defined 
here only apply within the context of this rulemaking.
    Act means the Clean Air Act, as amended, 42 U.S.C. 7401, et seq.
    Affected facility means, for the purposes of the regulatory 
compliance exemption of this part, affected facilities, as defined in 
part 60, subpart A of this chapter, that are subject to methane 
emissions requirements pursuant to part 60 of this chapter.
    Applicable facility means a facility within one or more of the 
following industry segments, as those industry segment terms are 
defined in Sec.  98.230 of this chapter. In the case where operations 
from two or more industry segments are co-located at the same part 98 
reporting facility, operations for all co-located segments constitute a 
single applicable facility under this part:
    (1) Offshore petroleum and natural gas production.
    (2) Onshore petroleum and natural gas production.
    (3) Onshore natural gas processing.
    (4) Onshore natural gas transmission compression.
    (5) Underground natural gas storage.
    (6) Liquefied natural gas storage.
    (7) Liquefied natural gas import and export equipment.
    (8) Onshore petroleum and natural gas gathering and boosting.
    (9) Onshore natural gas transmission pipeline.
    Carbon dioxide equivalent or CO2e means the number of 
metric tons of CO2 emissions with the same global warming 
potential as one metric ton of another greenhouse gas and is calculated 
using Equation A-1 in Sec.  98.2(b) of this chapter.
    Designated facility means, for purposes of the regulatory 
compliance exemption of this part, designated facilities, as defined in 
Sec.  60.21a(b) of this chapter, subject to methane emissions 
requirements pursuant to a state, Tribal, or Federal plan implementing 
part 60 of this chapter.
    e-GGRT ID number means the identification number assigned to a 
facility by the EPA's electronic Greenhouse Gas Reporting Tool for 
submission of the facility's part 98 report.
    Facility applicable emissions means the annual methane emissions, 
as calculated in Sec.  99.21, associated with a WEC applicable facility 
that are either equal to, below, or exceeding the waste emissions 
threshold for the WEC applicable facility prior to consideration of any 
applicable exemptions.
    Gas to oil ratio (GOR) means the ratio of the volume of gas at 
standard temperature and pressure that is produced from a volume of oil 
when depressurized to standard temperature and pressure.
    Gathering and boosting system means a single network of pipelines, 
compressors and process equipment, including equipment to perform 
natural gas compression, dehydration, and acid gas removal, that has 
one or more connection points to gas and oil production and a 
downstream endpoint, typically a gas processing plant, transmission 
pipeline, LDC pipeline, or other gathering and boosting system.
    Gathering and boosting system owner or operator means any person 
that holds a contract in which they agree to transport petroleum or 
natural gas from one or more onshore petroleum and natural gas 
production wells to a natural gas processing facility, another 
gathering and boosting system, a natural gas transmission pipeline, or 
a distribution pipeline, or any person responsible for custody of the 
petroleum or natural gas transported.

[[Page 5368]]

    Global warming potential or GWP means the ratio of the time-
integrated radiative forcing from the instantaneous release of one 
kilogram of a trace substance relative to that of one kilogram of a 
reference gas (i.e., CO2). GWPs for each greenhouse gas are 
provided in Table A-1 of part 98, subpart A of this chapter.
    Greenhouse gas or GHG means the air pollutants carbon dioxide 
(CO2), hydrofluorocarbons (HFCs), methane (CH4), 
nitrous oxide (N2O), perfluorocarbons (PFCs), and sulfur 
hexafluoride (SF6).
    Natural gas means a naturally occurring mixture or process 
derivative of hydrocarbon and non-hydrocarbon gases found in geologic 
formations beneath the earth's surface, of which its constituents 
include, but are not limited to, methane, heavier hydrocarbons and 
carbon dioxide. Natural gas may be field quality, pipeline quality, or 
process gas.
    Nonproduction sector means facilities in the onshore natural gas 
processing, the liquefied natural gas storage, the liquefied natural 
gas import and export equipment, and the onshore petroleum and natural 
gas gathering and boosting industry segments as those industry segments 
are defined in Sec.  98.230 of this chapter.
    Onshore natural gas transmission pipeline owner or operator means, 
for interstate pipelines, the person identified as the transmission 
pipeline owner or operator on the Certificate of Public Convenience and 
Necessity issued under 15 U.S.C. 717f, or, for intrastate pipelines, 
the person identified as the owner or operator on the transmission 
pipeline's Statement of Operating Conditions under section 311 of the 
Natural Gas Policy Act, or for pipelines that fall under the ``Hinshaw 
Exemption'' as referenced in section 1(c) of the Natural Gas Act, 15 
U.S.C. 717-717 (w)(1994), the person identified as the owner or 
operator on blanket certificates issued under 18 CFR 284.224. If an 
intrastate pipeline is not subject to section 311 of the Natural Gas 
Policy Act (NGPA), the onshore natural gas transmission pipeline owner 
or operator is the person identified as the owner or operator on 
reports to the state regulatory body regulating rates and charges for 
the sale of natural gas to consumers.
    Onshore petroleum and natural gas production owner or operator 
means the person or entity who holds the permit to operate petroleum 
and natural gas wells on the drilling permit or an operating permit 
where no drilling permit is issued, which operates a facility in the 
onshore petroleum and/or natural gas production industry segment (as 
that industry segment is defined in Sec.  98.230(a)(2) of this 
chapter). Where petroleum and natural gas wells operate without a 
drilling or operating permit, the person or entity that pays the State 
or Federal business income taxes is considered the owner or operator.
    Operator means, except as otherwise defined in this section, any 
person who operates or supervises a facility.
    Owner means, except as otherwise defined in this section, any 
person who has legal or equitable title to, has a leasehold interest 
in, or control of an applicable facility, except a person whose legal 
or equitable title to or leasehold interest in the facility arises 
solely because the person is a limited partner in a partnership that 
has legal or equitable title to, has a leasehold interest in, or 
control of the facility shall not be considered an ``owner'' of the 
facility.
    Part 98 report means the annual report required under part 98 of 
this chapter for owners and operators of certain facilities under the 
Petroleum and Natural Gas Systems source category.
    Petroleum means oil removed from the earth and the oil derived from 
tar sands and shale.
    Production sector means facilities in the offshore petroleum and 
natural gas production and the onshore petroleum and natural gas 
production industry segments as those industry segments are defined in 
Sec.  98.230 of this chapter.
    Reporting year means the calendar year during which data are 
required to be collected for purposes of the annual WEC filing. For 
example, reporting year 2024 is January 1, 2024 through December 31, 
2024, and the annual WEC filing for reporting year 2024 is submitted to 
EPA by March 31, 2025.
    Standard temperature and pressure means 60 [deg]F and 14.7 psia.
    Transmission sector means facilities in the onshore natural gas 
transmission compression, the underground natural gas storage, and the 
onshore transmission pipeline industry segments as those industry 
segments are defined in Sec.  98.230 of this chapter.
    Waste emissions threshold means the metric tons of methane 
emissions calculated by multiplying WEC applicable facility throughput 
by the industry segment-specific methane intensity thresholds 
established in CAA 136(f) and the density of methane (0.0192 metric ton 
per thousand standard cubic feet).
    WEC means waste emissions charge, the charge established in CAA 
136(c) on methane emissions that exceed certain thresholds.
    WEC applicable emissions means the annual methane emissions, as 
calculated in Sec.  99.21, associated with a WEC applicable facility 
that are either equal to, below, or exceeding the waste emissions 
threshold for the WEC applicable facility after consideration of any 
applicable exemptions.
    WEC applicable facility means an applicable facility, as defined in 
this section, for which the owner or operator of the part 98 reporting 
facility reports GHG emissions under part 98, subpart W of this chapter 
of more than 25,000 metric tons CO2e.
    WEC filing means the report and payment of applicable WEC 
obligation required to be submitted by a WEC obligated party under the 
requirements of this chapter. The WEC filing contains information 
regarding the WEC obligated party and WEC applicable facilities for the 
previous reporting year. For example, the WEC filing due on March 31, 
2025 contains information regarding reporting year 2024, which is 
January 1, 2024 through December 31, 2024.
    WEC obligated party means the owner or operator as defined in this 
section for the applicable industry segment as of December 31 of the 
reporting year. In cases where a WEC applicable facility has more than 
one owner or operator, the WEC obligated party shall be a person or 
entity selected by an agreement binding on each of the owners and 
operators involved in the transaction, following the provisions of 
Sec.  99.4(b).
    WEC obligation means the WEC charge amount resulting from the 
calculations in Sec.  99.23.
    You means a WEC obligated party subject to this part 99.


Sec.  99.3  Who must file?

    WEC obligated parties, as defined in Sec.  99.2, are required to 
submit a WEC filing and remit applicable WEC obligations and charges.


Sec.  99.4  How do I authorize and what are the responsibilities of the 
designated representative?

    Each WEC obligated party must follow the procedures in paragraphs 
(a) through (l) of this section, as applicable, to identify a WEC 
obligated party designated representative. In cases where a WEC 
applicable facility has more than one owner or operator, the WEC 
obligated party shall be a person or entity selected by an agreement 
binding on each of the owners and operators involved in the 
transaction, following the provisions of paragraph (b) of this section. 
Failure to select a WEC obligated party for each WEC

[[Page 5369]]

applicable facility with multiple owners or operators following the 
procedures of paragraph (b) of this section is considered a violation 
of this part for each owner and operator (as defined in Sec.  99.2 of 
this part) for the applicable industry segment of the associated WEC 
applicable facility.
    (a) General. Except as provided under paragraph (f) of this 
section, each WEC obligated party that is subject to this part shall 
have one designated representative, who shall be responsible for 
certifying, signing, and submitting WEC filings or other submissions to 
the Administrator under this part.
    (b) Authorization of a designated representative. The designated 
representative of each WEC obligated party shall be an individual 
selected by an agreement binding on the owner and operator of such 
entity and shall act in accordance with the certification statement in 
paragraph (i)(3)(iv) of this section. Failure of a WEC obligated party 
to authorize a designated representative following the procedures of 
this section is considered a violation of this part.
    (c) Responsibility of the designated representative. Upon receipt 
by the Administrator of a complete certificate of representation under 
this section for the WEC obligated party, the designated representative 
identified in such certificate of representation shall represent and, 
by his or her representations, actions, inactions, or submissions, 
legally bind the owner and operator of such an entity in all matters 
pertaining to this part, notwithstanding any agreement between the 
designated representative and said owner and operator. The owner and 
operator shall be bound by any decision or order issued to the 
designated representative by the Administrator or a court.
    (d) Timing. No WEC filing or other submissions under this part for 
a WEC obligated party will be accepted until the Administrator has 
received a complete certificate of representation under this section 
for a designated representative of the WEC obligated party. Such 
certificate of representation shall be submitted at least 60 days 
before the deadline for submission of the WEC obligated party's WEC 
filing under Sec.  99.5.
    (e) Certification of the WEC filing. Each WEC filing and any other 
submission under this part for a WEC obligated party shall be 
certified, signed, and submitted by the designated representative or 
any alternate designated representative of the WEC obligated party in 
accordance with this section and Sec.  3.10 of this chapter.
    (1) Each such submission shall include the following certification 
statement signed by the designated representative or any alternate 
designated representative: ``I am authorized to make this submission on 
behalf of the owner and operator of the WEC obligated party, for which 
the submission is made. I certify under penalty of law that I have 
personally examined, and am familiar with, the statements and 
information submitted in this document and all its attachments. Based 
on my inquiry of those individuals with primary responsibility for 
obtaining the information, I certify that the statements and 
information are to the best of my knowledge and belief true, accurate, 
and complete. I am aware that there are significant penalties for 
submitting false statements and information or omitting required 
statements and information, including the possibility of fine or 
imprisonment.''
    (2) The Administrator will accept a WEC filing or other submission 
for a WEC obligated party under this part only if the submission is 
certified, signed, and submitted in accordance with this section.
    (f) Alternate designated representative. A certificate of 
representation under this section for the WEC obligated party may 
designate one alternate designated representative, who shall be an 
individual selected by an agreement binding on the owner and operator, 
and may act on behalf of the WEC obligated party designated 
representative. The agreement by which the alternate designated 
representative is selected shall include a procedure for authorizing 
the alternate designated representative to act in lieu of the 
designated representative.
    (1) Upon receipt by the Administrator of a complete certificate of 
representation under this section for a WEC obligated party identifying 
an alternate designated representative, the following apply.
    (i) The alternate WEC obligated party designated representative may 
act on behalf of the WEC obligated party designated representative.
    (ii) Any representation, action, inaction, or submission by the 
alternate designated representative shall be deemed to be a 
representation, action, inaction, or submission by the WEC obligated 
party designated representative.
    (2) Except in this section, whenever the term ``designated 
representative'' is used in this part, the term shall be construed to 
include the designated representative or any alternate designated 
representative.
    (g) Changing a designated representative or alternate designated 
representative. The designated representative or alternate designated 
representative identified in a complete certificate of representation 
under this section for a WEC obligated party received by the 
Administrator may be changed at any time upon receipt by the 
Administrator of another later signed, complete certificate of 
representation under this section for the WEC obligated party. 
Notwithstanding any such change, all representations, actions, 
inactions, and submissions by the previous designated representative or 
the previous alternate designated representative of the WEC obligated 
party before the time and date when the Administrator receives such 
later signed certificate of representation shall be binding on the new 
designated representative and the owner and operator of the WEC 
obligated party.
    (h) Changes in the WEC obligated party. Within 90 days after any 
change in the WEC obligated party, the designated representative or any 
alternate designated representative shall submit a certificate of 
representation that is complete under this section to reflect the 
change.
    (i) Certificate of representation. A certificate of representation 
shall be complete if it includes the following elements in a format 
prescribed by the Administrator in accordance with this section:
    (1) Identification of the WEC obligated party for which the 
certificate of representation is submitted.
    (2) The name, organization name (company affiliation-employer), 
address, email address, telephone number, and facsimile transmission 
number (if any) of the designated representative and any alternate 
designated representative.
    (3) The following certification statements by the designated 
representative and any alternate designated representative:
    (i) ``I certify that I was selected as the designated 
representative or alternate designated representative, as applicable, 
by an agreement binding on the owner and operator of the entity.''
    (ii) ``I certify that I have all the necessary authority to carry 
out my duties and responsibilities under 40 CFR part 99 on behalf of 
the owner and operator of the entity and that such owner and operator 
shall be fully bound by my representations, actions, inactions, or 
submissions.''
    (iii) ``I certify that the owner and operator of the entity, as 
applicable, shall be bound by any order issued to me by the 
Administrator or a court regarding the entity.''

[[Page 5370]]

    (iv) ``If there are multiple owners and operators of the entity, I 
certify that I have given a written notice of my selection as the 
`designated representative' or `alternate designated representative', 
as applicable, and of the agreement by which I was selected to each 
owner and operator of the entity.''
    (4) The signature of the designated representative and any 
alternate designated representative and the dates signed.
    (j) Documents of agreement. Unless otherwise required by the 
Administrator, documents of agreement referred to in the certificate of 
representation shall not be submitted to the Administrator. The 
Administrator shall not be under any obligation to review or evaluate 
the sufficiency of such documents, if submitted.
    (k) Binding nature of the certificate of representation. Once a 
complete certificate of representation under this section for a WEC 
obligated party has been received, the Administrator will rely on the 
certificate of representation unless and until a later signed, complete 
certificate of representation under this section for the facility is 
received by the Administrator.
    (l) Objections concerning a designated representative.
    (1) Except as provided in paragraph (g) of this section, no 
objection or other communication submitted to the Administrator 
concerning the authorization, or any representation, action, inaction, 
or submission, of the designated representative or alternate designated 
representative shall affect any representation, action, inaction, or 
submission of the designated representative or alternate designated 
representative, or the finality of any decision or order by the 
Administrator under this part.
    (2) The Administrator will not adjudicate any private legal dispute 
concerning the authorization or any representation, action, inaction, 
or submission of any designated representative or alternate designated 
representative.


Sec.  99.5  When must I file and remit the applicable WEC obligation?

    Each WEC obligated party must submit their WEC filing including the 
information specified in Sec.  99.7 and remit applicable WEC obligation 
no later than March 31 of the year following the reporting year. All 
filing revisions must be received according to the schedule in Sec.  
99.7(e) to be considered for revisions to WEC obligations. If the 
submission date falls on a weekend or a federal holiday, the submission 
date shall be extended to the next business day.


Sec.  99.6  How do I file?

    Each WEC filing, certificate of representation, and remittance of 
applicable WEC fees for the WEC obligated party must be submitted 
electronically in accordance with the requirements of this part and in 
a format specified by the Administrator.


Sec.  99.7  What are the general reporting, recordkeeping, and 
verification requirements of this part?

    The WEC obligated party that is subject to the requirements of this 
part must submit a WEC filing to the Administrator as specified in this 
section.
    (a) Schedule. The WEC filing must be submitted in accordance with 
Sec.  99.5.
    (b) Content of the WEC filing. For each WEC obligated party, report 
the information in paragraphs (b)(1)(i) through (v) of this section. 
For each WEC applicable facility under common ownership or control of 
the WEC obligated party, report the information in paragraphs (b)(2)(i) 
through (vii) of this section. The WEC filing must also include payment 
of applicable WEC obligation, as specified in paragraph (b)(3) of this 
section.
    (1) Reporting requirements at the WEC obligated party level.
    (i) The company name.
    (ii) The United States address for the company.
    (iii) The name, address, email address, and phone number for the 
designated representative for the WEC obligated party.
    (iv) The list of e-GGRT ID number(s) under which the WEC applicable 
facilities comprising the WEC obligated party as of December 31 of the 
reporting year report under part 98, subpart W of this chapter.
    (v) The net WEC emissions, as calculated pursuant to Sec.  99.22, 
and WEC obligation, as calculated pursuant to Sec.  99.23, for the WEC 
obligated party.
    (2) Reporting requirements for each WEC applicable facility 
comprising the WEC obligated party.
    (i) The e-GGRT ID under which the WEC applicable facility emissions 
are reported under part 98, subpart W of this chapter.
    (ii) The industry segment(s) for the WEC applicable facility.
    (iii) For WEC applicable facilities in the offshore petroleum and 
natural gas production or onshore petroleum and natural gas production 
industry segment as defined in Sec.  99.2, if conditions specified in 
Sec.  99.30 regarding emissions from delays in permitting are met, 
provide information as specified in Sec.  99.31.
    (iv) If the conditions specified in Sec.  99.40 are met regarding 
the regulatory compliance exemption, report whether the WEC applicable 
facility contains any affected facilities under part 60 of this chapter 
or any designated facilities under an applicable approved state, 
Tribal, Federal plan in part 62 of this chapter. If so, provide the 
information specified in Sec.  99.41, as applicable.
    (v) For WEC applicable facilities in the offshore petroleum and 
natural gas production or onshore petroleum and natural gas production 
industry segment as defined in Sec.  99.2, if conditions specified in 
Sec.  99.50 regarding emissions from permanently shut-in and plugged 
wells are met, you must report the information specified in Sec.  
99.51.
    (vi) The facility waste emissions threshold as calculated pursuant 
to Sec.  99.20, and, if there is more than one applicable industry 
segment within the WEC applicable facility, each industry segment waste 
emissions threshold for each applicable industry segment within the 
applicable facility, as calculated pursuant to Sec.  99.20.
    (vii) The facility applicable emissions, as calculated pursuant to 
Sec.  99.21 and the WEC applicable emissions, as calculated pursuant to 
Sec.  99.21.
    (3) Payment of applicable WEC obligation, submitted in accordance 
with Sec.  99.9.
    (c) Verification of the WEC filing. To verify the completeness and 
accuracy of WEC filing, the EPA will consider the verification status 
of part 98 reports, and may review the certification statements 
described in Sec.  99.4 and any other credible evidence, in conjunction 
with a comprehensive review of the WEC filing, including attachments. 
The EPA may conduct audits of selected WEC obligated parties and 
associated WEC applicable facilities. During such audits, the records 
generated under this part must be made available to the EPA. The on-
site audits may be conducted by private auditors contracted by the EPA 
or by Federal, State or local personnel, as appropriate, and may be 
required to be arranged by and conducted at the expense of the WEC 
obligated party. Nothing in this section prohibits the EPA from using 
additional information, including reports, prepared and submitted in 
accordance with part 60 of this chapter, or an applicable approved 
state, Tribal, or Federal plan under part 62 of this chapter that 
implements the emission guidelines contained in part 60 of this 
chapter, to verify the completeness and accuracy of the filings.

[[Page 5371]]

    (d) Recordkeeping. Retain all required records for at least 5 years 
from the date of submission of the WEC filing for the reporting year in 
which the record was generated. The records shall be kept in an 
electronic or hard-copy format (as appropriate) and recorded in a form 
that is suitable for expeditious inspection and review. Upon request by 
the Administrator, the records required under this section must be made 
available to EPA. Records may be retained off site if the records are 
readily available for expeditious inspection and review. For records 
that are electronically generated or maintained, the equipment or 
software necessary to read the records shall be made available, or, if 
requested by EPA, electronic records shall be converted to paper 
documents. You must retain the following records:
    (1) All information required to be retained by part 98, subparts A 
and W of this chapter.
    (2) Any other information not included in a part 98 report used to 
complete the WEC filing.
    (3) All information required to be submitted as part of the WEC 
filing.
    (e) Annual WEC filing revisions. Except as specified in paragraph 
(e)(2) of this section, the provisions of this paragraph (e) apply 
until November 1 of the year following the reporting year, or for a 
given reporting year after the November 1 deadline if the resubmission 
is related to the resolution of unverified data process specified at 
Sec.  99.8.
    (1) The WEC obligated party shall submit a revised WEC filing 
within 45 days of discovering that a previously submitted WEC filing 
contains one or more substantive errors. The revised WEC filing must 
correct all substantive errors. If the resubmission is due to a 
correction in a part 98 report resubmitted by a WEC applicable 
facility, the WEC obligated party must report the number of corrections 
made in the part 98 report(s) and a description of how the changes 
impact the assessment of the WEC obligation.
    (2) The revisions for substantive errors as described in paragraph 
(e)(2)(i) and (ii) are not subject to the November 1 deadline and must 
be submitted according the schedule therein.
    (i) Revised filings for purposes of the regulatory compliance 
exemption must be submitted as follows:
    (A) Revised filings to submit a CAA section 111(b) or (d) 
compliance report which covers the remaining portion of a WEC filing 
year, which were not available at the time of the WEC filing, must be 
submitted on or before the date that the compliance report covering the 
remainder of the year is due under the applicable requirements of CAA 
section 111(b) or (d), as applicable.
    (B) Revised filings to submit findings by the WEC obligated party 
that one or more deviations or violations discovered after the WEC 
filing must be submitted within 45 days of the discovery.
    (ii) The Administrator may notify the WEC obligated party in 
writing that a WEC filing previously submitted by the owner or operator 
contains one or more substantive errors. Such notification will 
identify each such substantive error. The WEC obligated party shall, 
within 45 days of receipt of the notification, either resubmit the WEC 
filing that, for each identified substantive error, corrects the 
identified substantive error (in accordance with the applicable 
requirements of this part) or provide information demonstrating that 
the previously submitted report does not contain the identified 
substantive error or that the identified error is not a substantive 
error. The EPA reserves to right to revise WEC obligations for a given 
reporting year after the November 1 final resubmission deadline if data 
errors are discovered by EPA at a later date.
    (3) A substantive error is an error that impacts the 
Administrator's ability to accurately calculate a WEC obligated party's 
WEC obligation, which may include, but is not limited to, the list of 
WEC applicable facilities associated with a WEC obligated party, the 
emissions or throughput reported in the WEC applicable facility part 98 
report(s), emissions associated with exemptions, and supporting 
information for each exemption to demonstrate its validity.
    (4) Notwithstanding paragraphs (e)(1) and (2) of this section, upon 
request the Administrator may provide an extension of the 45-day period 
for submission of a revised report or information under paragraphs 
(e)(1) and (2) of this section if adequate justification is provided by 
the WEC obligated party. The Administrator may provide an extension of 
up to 30 days provided that the request is received by email to an 
address prescribed by the Administrator prior to the expiration of the 
45-day period and that the request demonstrates that it is not 
practicable to submit a revised report or information under paragraphs 
(e)(1) and (2) of this section within 45 days.
    (5) The WEC obligated party shall retain documentation for 5 years 
to support any revision made to a WEC filing.
    (6) If a facility changes ownership such that there is a change to 
the WEC obligated party, the entity that was the WEC obligated party at 
the time of the original filing for a reporting year remains 
responsible for any revisions to WEC filings for that reporting year.
    (f) Designation of unverified filings and reports. Following the 
verification process discussed in Sec.  98.3(h) of this chapter for 
part 98 reports and paragraph (c) of this section for WEC filings, the 
EPA shall designate:
    (1) The annual part 98 report associated with each WEC applicable 
facility as either verified or unverified. An unverified report is one 
in which the EPA has provided notification under Sec.  98.3(h)(2) of 
this chapter and the owner or operator of the WEC applicable facility 
has failed to revise and resubmit the report and resolve the error or 
provide justification to the satisfaction of the EPA that the 
identified error is not a substantive error (in accordance with the 
applicable requirements of Sec.  98.3(h)(3) of this chapter).
    (2) The annual WEC filing from each WEC obligated party submitted 
pursuant to Sec.  99.7 as either verified or unverified. An unverified 
filing is one in which the EPA has provided notification under Sec.  
99.7(e)(2) and the WEC obligated party designated representative has 
failed to resubmit the report and for each identified substantive error 
correct the identified substantive error (in accordance with the 
applicable requirements of paragraph (e)(3) of this section) or provide 
information demonstrating that the submitted report does not contain 
the identified substantive error or that the identified error is not a 
substantive error. The determination of verification status of a part 
98 report under paragraph (f)(1) of this section will be taken into 
consideration in the determination of the verification status of a WEC 
filing.


Sec.  99.8  What are the general provisions for assessment of the WEC 
obligation?

    (a) Assessment of the WEC obligation. WEC obligation assessments 
shall be made pursuant to Sec.  99.23 on the basis of information 
submitted by the date specified in Sec.  99.5 and following the 
submittal requirements of Sec.  99.6.
    (b) Assessment of the WEC obligation for unverified filings. If a 
WEC filing is unverified but the EPA is able to correct the error(s) 
based on reported data, the EPA will recalculate the WEC using 
available information and provide an invoice or refund to the WEC 
obligated party within 60 days of determining a WEC filing to be 
unverified. If the WEC obligated party resubmits a WEC filing within 
that timeframe, the EPA will

[[Page 5372]]

either verify the resubmission, or take the resubmission into account 
when calculating the WEC.
    (c) Third-party audits for unverified reports. If the EPA is unable 
to calculate the WEC with available information, the EPA may require 
the WEC obligated party to undergo a third party audit. The EPA may 
require the WEC obligated party to fund and arrange the third-party 
audit. The third-party auditor must review records kept by the WEC 
obligated party, quantify the WEC with available information, and the 
updated WEC calculations and supporting data must be submitted to the 
EPA. The EPA will then take that information into consideration and 
calculate the WEC and provide an invoice or refund to the WEC obligated 
party.
    (1) Third party reviews. An independent third-party audit of the 
information provided shall be based on a review of the relevant 
documents and shall identify each item required by the WEC filing, 
describe how the independent third-party evaluated the accuracy of the 
information provided, state whether the independent third-party agrees 
with the information provided, and identify any exceptions between the 
independent third-party's findings and the information provided.
    (i) Audits required under this section must be conducted by a 
certified independent third-party. The auditor must have professional 
work experience in the petroleum engineering field or related to oil 
and gas production, gathering, processing, transmission or storage.
    (ii) To be considered an independent third-party, the independent 
third party shall not be operated by the WEC obligated party and the 
independent third party shall be free from any interest in the WEC 
obligated party's business.
    (iii) The independent third-party shall submit all records 
pertaining to the audit required under this section, including 
information supporting all of the requirements of Sec.  99.8(c)(1) to 
the WEC obligated party.
    (iv) The independent third-party must provide to the WEC obligated 
party documentation of qualifications of professional work experience 
in the petroleum engineering field or related to oil and gas 
production, gathering, processing, transmission or storage.
    (2) Reporting and recordkeeping requirements for WEC obligated 
parties following third party audits.
    (i) The WEC obligated party shall provide to EPA the results of the 
third-party audit, including the WEC obligation amount and all 
supporting documentation information that is included in reporting 
requirements under Sec. Sec.  99.7, and 99.31, 99.41, and 99.51, as 
applicable.
    (ii) The WEC obligated party shall provide to EPA documentation of 
qualifications of the third-party auditor.
    (iii) The WEC obligated party shall retain all records pertaining 
to the audit required under this section for a period of 5 years from 
the date of creation and shall deliver such records to the 
Administrator upon request.
    (d) Resubmittal of filings and reports for the current or prior 
reporting year. If resubmittal of a previously submitted part 98 report 
and/or WEC filing, submitted as specified in Sec.  99.7(e), results in 
a change to the WEC obligation determined for a WEC obligated party for 
the reporting year the following process shall apply:
    (1) If the WEC obligation based upon the resubmitted report or 
filing for the reporting year is less than the WEC obligation 
previously remitted by the WEC obligated party, the Administrator shall 
authorize a refund to the WEC obligated party equal to the difference 
in WEC obligation.
    (2) If the WEC obligation based upon the resubmitted report or 
filing for the reporting year is greater than the WEC obligation 
previously remitted by the WEC obligated party, the Administrator shall 
issue an invoice to the WEC obligated party containing a charge in the 
amount determined using Equation A-1 of this section. Interest shall 
not be assessed for a change in WEC obligation resulting from the 
timely submittal of a regulatory report in accordance with Sec.  
99.41(c).
[GRAPHIC] [TIFF OMITTED] TP26JA24.000

Where:

WECr = The charge obligation of the WEC obligated party 
to be resubmitted for the difference in WEC obligation, including 
any applicable interest, in dollars.
[Delta]WEC = The difference in WEC obligation, calculated as the 
amount remitted upon the original submittal specified in Sec.  99.5 
subtracted from the quantity of WEC obligation determined based upon 
the resubmitted report or filing, in dollars.
iCVFR = The Treasury Current Value of Funds Rate as 
specified in Sec.  99.10(b).
t = The number of days after the deadline specified in Sec.  99.5 
for remittance of WEC obligation for the reporting year that the 
resubmitted WEC filing or part 99 report was received by the 
Administrator, in days. For example, if a reporting year 2024 part 
99 report is resubmitted on April 28, 2025, ``t'' is equal to 28 
days. If a reporting year 2024 part 99 report is resubmitted on 
April 28, 2026, ``t'' is equal to 393 days.
365 = Conversion factor from years to days.


Sec.  99.9  How are payments required by this part made?

    (a) The WEC obligation owed for each reporting year must be paid by 
the WEC obligated party as part of the annual WEC filling, as required 
by Sec.  99.7(b), and is considered due at the date specified in Sec.  
99.5.
    (b) Other than the WEC obligation specified in paragraph (a) of 
this section, all other charges required by this part, including 
adjusted WEC obligations, interest fees, and penalties, shall be paid 
by the WEC obligated party in response to an electronic invoice or bill 
by the specified due date, or within 30 days of the date of the invoice 
or bill if a due date is not provided.
    (c) All WEC obligations, interest fees, and penalties required by 
this subpart shall be paid to the Department of the Treasury by the WEC 
obligated party electronically in U.S. dollars, using an online 
electronic payment service specified by the Administrator.


Sec.  99.10  What fees apply to delinquent payments?

    (a) Delinquency. WEC obligated party accounts are delinquent if the 
WEC obligation payment is not submitted in full by the date required by 
Sec.  99.5. WEC obligated party accounts are also delinquent if the 
accounts remain unpaid after the due date specified in the invoice or 
other notice of the WEC amount owed.
    (b) Interest fee. In accordance with 31 U.S.C. 3717(a), delinquent 
WEC obligated party accounts shall be charged a minimum annual rate of 
interest equal to the average investment rate for Treasury tax and loan 
accounts (Current Value of Funds Rate or CVFR) most recently published 
and in effect by the Secretary of the Treasury.
    (c) Non-payment penalty. In accordance with 31 U.S.C. 3717(e), WEC

[[Page 5373]]

obligated party accounts that are more than 90 days past due shall be 
charged an additional penalty of 6% per year assessed on any part of 
the debt that is past due for more than 90 days.
    (d) Penalty for non-submittal. In accordance with 42 U.S.C. 
7413(d)(1), a WEC obligated party that fails to submit an annual WEC 
filing by the date specified in Sec.  99.5 may be charged an 
administrative penalty. The penalty assessment shall be a daily 
assessment per day that the WEC filing is not submitted, assessed up to 
the value specified in Table 1 of Sec.  19.4, as amended, of this 
chapter. The assessment of penalty shall begin on the date that the WEC 
filing was considered past due per Sec.  99.5 and continue until such 
time that the WEC filing is submitted by the WEC obligated party's 
designated representative.


Sec.  99.11  What are the compliance and enforcement provisions of this 
part?

    Any violation of any requirement of this part shall be a violation 
of the Clean Air Act, including section 114 (42 U.S.C. 7414) and 
section 136 (42 U.S.C. 7436). A violation would include, but is not 
limited to, failure to submit a WEC filing, failure to collect data 
needed to calculate the WEC charge (including any data relevant to 
determining the applicability of any exemptions), failure to select a 
WEC obligated party, failure to retain records needed to verify the 
amount of WEC charge, providing false information in a WEC filing, and 
failure to remit WEC payment. Each day of a violation would constitute 
a separate violation. Each day of each violation constitutes a separate 
violation. Any penalty assessed shall be in addition to any WEC 
obligation due under this part and any fees applicable to delinquent 
payments due under Sec.  99.10.


Sec.  99.12  What addresses apply for this part?

    All requests, notifications, and communications to the 
Administrator pursuant to this part must be submitted electronically 
and in a format as specified by the Administrator.


Sec.  99.13  What are the confidentiality determinations and related 
procedures for this part?

    This section characterizes various categories of information for 
purposes of making confidentiality determinations, as follows:
    (a) This paragraph (a) applies the definition of ``Emission data'' 
in 40 CFR 2.301(a) for information reported under this part. ``Emission 
data'' cannot be treated as confidential business information and shall 
be available to be disclosed to the public. The following categories of 
information qualify as emission data:
    (1) Methane emission information, including the net WEC emissions, 
waste emissions thresholds, WEC applicable emissions, and the quantity 
of methane emissions to be exempted due to unreasonable delay and wells 
that were permanently shut-in and abandoned.
    (2) Calculation methodology, including the method used to determine 
the quantity of methane emissions to be exempted due to an unreasonable 
permitting delay and the method used to quantify emissions exempted 
from permanently shut-in and plugged wells.
    (3) Facility and unit identifier information, including WEC 
obligated party company name and address, the name and contact 
information for the designated representative of WEC obligated party, 
signed and dated certification statements of the accuracy and 
completeness of the report, facility identifiers (e.g., e-GGRT ID 
number), industry segment, well-pad and/or well identifiers, and 
emission source-specific methane mitigation activities impacted by an 
unreasonable permitting delay.
    (b) The following types of information are not eligible for 
confidential treatment:
    (1) The WEC obligation, as calculated pursuant to Sec.  99.23.
    (2) Compliance information, including information regarding 
applicable emissions standards or other relevant standards of 
performance or requirements, information in construction or operating 
permits, and information submitted to document compliance with an 
emissions standard or a standard of performance, such as a periodic 
report, prepared and submitted in accordance with part 60 of this 
chapter, or an applicable approved state, Tribal, or Federal plan under 
part 62 of this chapter that implements the emission guidelines 
contained in part 60 of this chapter, (excluding any information 
redacted from the report and claimed as confidential).
    (3) Published information that is publicly available, including 
information that is made available through publication of annual 
reports submitted under part 98 of this chapter, on company or other 
websites, or otherwise made publicly available.
    (c) If you submit information that is not described in paragraphs 
(a) and (b) of this section, you may claim the information as 
confidential and the information is subject to the process for 
confidentiality determinations in 40 CFR part 2 as described in 
Sec. Sec.  2.201 through 2.208. We may require you to provide us with 
information to substantiate your claims. If claimed, we may consider 
this substantiating information to be confidential to the same degree 
as the information for which you are requesting confidential treatment. 
We will make our determination based on your statements to us, the 
supporting information you send us, and any other available 
information. However, we may determine that your information is not 
subject to confidential treatment consistent with 40 CFR part 2 and 5 
U.S.C. 552(b)(4).
    (d) Submitted applications and reports typically rely on software 
or templates to identify specific categories of information. If you 
submit information in a comment field designated for users to add 
general information, we will respond to requests for disclosing that 
information consistent with paragraphs (a) through (c) of this section.

Subpart B--Determining Waste Emissions Charge


Sec.  99.20  How will the waste emissions threshold for each WEC 
applicable facility be determined?

    The methane waste emissions threshold for each applicable industry 
segment within a WEC applicable facility for the reporting year will be 
calculated as described in paragraphs (a) through (d) of this section, 
as applicable. The methane waste emissions threshold for each WEC 
applicable facility will be determined as described in paragraph (e) of 
this section.
    (a) For each offshore petroleum and natural gas production industry 
segment or onshore petroleum and natural gas production industry 
segment that sends natural gas to sale at a WEC applicable facility, 
the facility waste emissions threshold will be calculated using 
Equation B-1 of this section.
[GRAPHIC] [TIFF OMITTED] TP26JA24.015


[[Page 5374]]


Where:

THis,Prod = The methane waste emissions threshold for the 
industry segment at a WEC applicable facility for the reporting year 
in the production sector that has natural gas sent to sale, metric 
tons (mt) CH4.
0.002 = Industry segment-specific methane intensity threshold, as 
specified in CAA section 136(f), for methane emissions for 
applicable facilities with natural gas sales in the production 
sector, thousand standard cubic feet (Mscf) CH4 per Mscf 
of natural gas sent to sale.
[rho]CH4 = Density of methane = 0.0192 kilograms per 
standard cubic foot (kg/scf) = 0.0192 metric tons per thousand 
standard cubic feet (mt/Mscf).
Qng,Prod = The total quantity of natural gas that is sent 
to sale from the WEC applicable facility in the reporting year, as 
reported pursuant to part 98, subpart W of this chapter. For onshore 
petroleum and natural gas production, you must use the quantity 
reported pursuant to proposed Sec.  98.236(aa)(1)(i)(B) of this 
chapter, in Mscf. For offshore petroleum and natural gas production, 
you must use the quantity reported pursuant to proposed Sec.  
98.236(aa)(2)(i) of this chapter, in Mscf.

    (b) For each offshore petroleum and natural gas production industry 
segment or the onshore petroleum and natural gas production industry 
segment that has no natural gas sent to sale at a WEC applicable 
facility, the facility waste emissions threshold will be calculated 
using Equation B-2 of this section.
[GRAPHIC] [TIFF OMITTED] TP26JA24.016

Where:

THis,Prod = The annual methane waste emissions threshold 
for the industry segment at a WEC applicable facility in the 
production sector that has no natural gas sent to sale, mt 
CH4.
10 = Industry segment-specific methane intensity threshold, as 
specified in CAA section 136(f), for applicable facilities with no 
natural gas sales in the production sector, mt CH4 per 
million barrels oil sent to sale.
Qo,Prod = The total quantity of crude oil that is sent to 
sale from the WEC applicable facility in the reporting year, as 
reported pursuant to part 98, subpart W of this chapter. For onshore 
petroleum and natural gas production, you must use the quantity 
reported pursuant to proposed Sec.  98.236(aa)(1)(i)(C) of this 
chapter, in barrels. For offshore petroleum and natural gas 
production, you must use the quantity reported pursuant to proposed 
Sec.  98.236(aa)(2)(ii) of this chapter, in barrels.
10-6 = Conversion from barrels to million barrels.

    (c) For each onshore natural gas processing industry segment, 
liquefied natural gas storage industry segment, the liquefied natural 
gas import and export equipment industry segment, or the onshore 
petroleum and natural gas gathering and boosting industry segment at a 
WEC applicable facility, the facility waste emissions threshold will be 
calculated using Equation B-3 of this section.
[GRAPHIC] [TIFF OMITTED] TP26JA24.017

Where:

THis,NonProd = The annual methane waste emissions 
threshold for the industry segment at a WEC applicable facility in 
the nonproduction sector, mt CH4.
0.0005 = Industry segment-specific methane intensity threshold, as 
specified in CAA section 136(f), for applicable facilities in the 
nonproduction sector, Mscf CH4 per Mscf of natural gas 
sent to sale from or through the facility.
[rho]CH4 = Density of methane = 0.0192 kg/scf = 0.0192 
mt/Mscf.
Qng,NonProd = The total quantity of natural gas that is 
sent to sale from or through the industry segment at a WEC 
applicable facility in the reporting year as reported pursuant to 
part 98, subpart W of this chapter. For RY 2024 for onshore natural 
gas processing, you must use the quantity reported pursuant to Sec.  
98.236(aa)(3)(ii) of this chapter, in Mscf and for RY 2025 and 
later, you must use the quantity reported pursuant to proposed Sec.  
98.236(aa)(3)(ix) of this chapter, in Mscf. For LNG import and 
export, you must use sum of the quantities reported pursuant to 
Sec.  98.236(aa)(6) and (7) of this chapter, in Mscf. For LNG 
storage, you must use the quantity reported pursuant to Sec.  
98.236(aa)(8)(ii) of this chapter, in Mscf. For onshore petroleum 
and natural gas gathering and boosting, you must use the quantity 
reported pursuant to Sec.  98.236(aa)(10)(ii) of this chapter, in 
Mscf.

    (d) For each onshore natural gas transmission compression industry 
segment, underground natural gas storage industry segment, or onshore 
natural gas transmission pipeline industry segment at a WEC applicable 
facility, the facility waste emissions threshold will be calculated 
using Equation B-4 of this section.
[GRAPHIC] [TIFF OMITTED] TP26JA24.018

Where:

THis,Tran = The annual methane waste emissions threshold 
for the industry segment at a WEC applicable facility in the 
transmission sector, mt CH4.
0.0005 = Industry segment-specific methane intensity threshold, as 
specified in CAA section 136(f), for applicable facilities in the 
transmission sector, Mscf CH4 per Mscf of natural gas 
sent to sale from or through the facility.
[rho]CH4 = Density of methane = 0.0192 kg/scf = 0.0192 
mt/Mscf.
Qng,Tran = The total quantity of natural gas that is sent 
to sale from or through the industry segment at a WEC applicable 
facility in the reporting year as reported pursuant to part 98, 
subpart W of this chapter. For onshore natural gas transmission 
compression, you must use the quantity reported pursuant to Sec.  
98.236(aa)(4)(i) of this chapter, in Mscf. For underground natural 
gas storage, you must use the quantity reported pursuant to Sec.  
98.236(aa)(5)(ii) of this chapter, in Mscf. For onshore natural gas 
transmission pipeline, you must use the quantity reported pursuant 
to Sec.  98.236(aa)(11)(iv) of this chapter, in Mscf.

    (e) For each WEC applicable facility that operates in a single 
industry segment, the methane waste emissions threshold shall be equal 
to the value calculated in Equation B-1, Equation B-2, Equation B-3, or 
Equation B-4 of this section, as applicable. For each WEC applicable 
facility that operates in two or more industry segments, the facility 
waste emissions threshold will be

[[Page 5375]]

calculated using Equation B-5 of this section.
[GRAPHIC] [TIFF OMITTED] TP26JA24.019

Where:

THWAF = The WEC applicable facility waste emissions 
threshold, mt CH4.
THis,s = The industry segment waste emissions threshold, 
as calculated in Equation B-3 or Equation B-4 of this section, for 
each industry segment ``s'' at the WEC applicable facility, mt 
CH4.
N = Number of industry segments at the WEC applicable facility.


Sec.  99.21  How will the WEC applicable emissions for a WEC applicable 
facility be determined?

    (a) The total facility applicable emissions for each WEC applicable 
facility will be calculated using Equation B-6 of this section.
[GRAPHIC] [TIFF OMITTED] TP26JA24.020

Where:

ETFA,CH4 = The annual methane emissions equal to, below, 
or exceeding the waste emissions threshold for a WEC applicable 
facility prior to consideration of any applicable exemptions (i.e., 
total facility applicable emissions), mt CH4.
ESubpartW,CH4 = The annual methane emissions for a WEC 
applicable facility, as reported under part 98, subpart W of this 
chapter for the corresponding reporting year, mt CH4.
THWAF = The waste emissions threshold for a WEC 
applicable facility, as determined in Sec.  99.20(e), mt 
CH4.

    (b) If the total facility applicable emissions calculated using 
Equation B-6 of this section are less than or equal to 0 mt, then the 
WEC applicable emissions are equal to the total facility applicable 
emissions.
    (c) If the total facility applicable emissions calculated using 
Equation B-6 of this section are greater than 0 mt and the regulatory 
compliance exemption as specified in Sec.  99.40 applies to the WEC 
applicable facility, the WEC applicable emissions for that facility are 
equal to 0 mt.
    (d) If the total facility applicable emissions calculated using 
Equation B-6 of this section are greater than 0 mt and the regulatory 
compliance exemption as specified in Sec.  99.40 does not apply to the 
WEC applicable facility, the WEC applicable emissions for each WEC 
applicable facility will be calculated using Equation B-7 of this 
section.
[GRAPHIC] [TIFF OMITTED] TP26JA24.021

Where:

EWA,CH4 = The annual methane emissions associated with a 
WEC applicable facility that are either equal to, below, or 
exceeding the waste emissions threshold for the WEC applicable 
facility (i.e., the WEC applicable emissions), mt CH4. If 
the result of this calculation is less than 0 mt CH4, the 
WEC appliable emissions for the facility are equal to 0 mt 
CH4.
ETFA,CH4 = The annual methane emissions equal to, below, 
or exceeding the waste emissions threshold for a WEC applicable 
facility prior to consideration of any applicable exemptions for the 
reporting year, mt CH4.
EDelay,CH4 = The quantity of methane emissions exempted, 
as determined in Equation C-1 of Sec.  99.32, at the WEC applicable 
facility in the offshore petroleum and natural gas production or 
onshore petroleum and natural gas production industry segment due to 
an unreasonable delay in environmental permitting of gathering or 
transmission infrastructure, mt CH4.
EPlug,CH4 = The total quantity of annual methane 
emissions, as determined in Equation E-5 of Sec.  99.52, at the WEC 
applicable facility in the onshore petroleum and natural gas 
production and offshore petroleum and natural gas production 
industry segments, attributable to all wells that were permanently 
shut-in and plugged during the reporting year in accordance with all 
applicable closure requirements, mt CH4.


Sec.  99.22  How will the net WEC emissions for a WEC obligated party 
be determined?

    Net WEC emissions for a WEC obligated party, equal to the sum of 
WEC applicable emissions from all facilities with the same WEC 
obligated party, as specified in 99.2, will be calculated using 
Equation B-8 of this section.
[GRAPHIC] [TIFF OMITTED] TP26JA24.003

Where:

ENetWEC,CH4 = The annual methane emissions subject to the 
WEC for the WEC obligated party for the reporting year, mt 
CH4.
EWA,CH4 = The annual methane emissions equal to, below, 
or exceeding the waste emissions thresholds for a WEC applicable 
facility ``j'' as calculated in Sec.  99.21(b) or (d) under common 
ownership or control of a WEC obligated party, mt CH4.
N = Total number of WEC applicable facilities under common ownership 
or control of a WEC obligated party, excluding any WEC applicable 
facilities for which the regulatory compliance exemption as 
specified in Sec.  99.40 applies.

[[Page 5376]]

Sec.  99.23  How will the WEC Obligation for a WEC obligated party be 
determined?

    (a) If the net WEC emissions for a WEC obligated party as 
determined in Sec.  99.22 are less than or equal to zero, the WEC 
obligated party's WEC obligation is zero and the WEC obligated party is 
not subject to a waste emissions charge in the reporting year.
    (b) If the net WEC emissions for a WEC obligated party as 
determined in Sec.  99.22 are greater than zero, the WEC obligation 
will be calculated according to the applicable provisions in paragraphs 
(b)(1) through (3) of this section.
    (1) For reporting year 2024, multiply the net WEC emissions from 
Equation B-8 of this subpart by $900 per mt CH4 to determine 
the WEC obligation.
    (2) For reporting year 2025, multiply the net WEC emissions from 
Equation B-8 of this subpart by $1,200 per mt CH4 to 
determine the WEC obligation.
    (3) For reporting year 2026 and each year thereafter, multiply the 
net WEC emissions from Equation B-8 of this subpart by $1,500 per mt 
CH4 to determine the WEC obligation.

Subpart C--Unreasonable Delay Exemption


Sec.  99.30  Which facilities qualify for the exemption for emissions 
caused by an unreasonable delay in environmental permitting of 
gathering or transmission infrastructure?

    (a) The WEC applicable facility must be in the offshore petroleum 
and natural gas production or onshore petroleum and natural gas 
production industry segment as defined in Sec.  99.2.
    (b) The total facility applicable emissions for the WEC applicable 
facility as calculated in accordance with Sec.  99.21(a) must exceed 0 
mt.
    (c) All requests for information regarding the permit received by 
either the production entity potentially eligible for the exemption or 
the entity seeking the environmental permit must not have exceeded the 
response time requested by the permitting agency, or by the relevant 
production or gathering or transmission infrastructure entity seeking 
the permit, or exceeded 30 days if no specific response time is 
requested.
    (d) The WEC facility must report flaring emissions in the reporting 
year that occurred as a result of a delay in environmental permitting 
of gathering or transmission infrastructure, and are in compliance with 
all applicable local, state and federal regulations regarding flaring 
emissions.
    (e) [A set period of months (with exact timing to be specified at 
final)] must have passed since submission of a complete environmental 
permit application, as certified by the relevant permitting authority, 
to construct gathering or transmission infrastructure without approval 
or denial of the environmental permit application.


Sec.  99.31  What are the reporting requirements for the exemption for 
emissions caused by an unreasonable delay in environmental permitting 
of gathering or transmission infrastructure?

    (a) Upon meeting all criteria in Sec.  99.30(a) through (f), you 
shall report information regarding an exemption for unreasonable delay 
in permitting of gathering or transmission infrastructure for a given 
reporting year. The unreasonable delay exemption information to be 
reported is described in paragraph (b) of this section. The 
unreasonable delay exemption shall be submitted as described in 
paragraph (c) of this section.
    (b) For each unreasonable delay exemption, the WEC obligated party 
must report the information specified in paragraphs (b)(1) through (10) 
of this section.
    (1) The company name and name of the facility that submitted the 
permit application to construct and/or operate gathering or 
transmission infrastructure.
    (2) The name and e-GGRT ID number under part 98, subpart W of this 
chapter of the production facility impacted by the unreasonable delay 
in environmental permitting of gathering or transmission 
infrastructure.
    (3) The date of the initial permit request to build gathering or 
transmission infrastructure.
    (4) An attestation that the entity seeking the permit has been 
responsive to the relevant authority regarding the permit application, 
that is that the entity has responded to all requests from the 
permitting authority within the time frame requested by the relevant 
authority or within 30 days if no timeframe is specified.
    (5) For each well-pad impacted by the unreasonable delay in 
permitting of gathering or transmission infrastructure:
    (i) The well-pad ID for each well-pad, as reported under part 98, 
subpart W of this chapter.
    (ii) A listing of methane emissions mitigation activities that are 
impacted by the unreasonable permitting delay.
    (6) The estimated date to commence operation of the gathering or 
transmission infrastructure if application had been approved before 
[the set period of months elapsed (exact timing to be specified at 
final)].
    (7) If the application has been approved and operations commenced 
during the reporting year, the first date that offtake to the gathering 
or transmission infrastructure from the implementation of methane 
emissions mitigation occurred.
    (8) The beginning and ending date for which the eligible delay 
limited the offtake of Nnatural gas associated with methane emissions 
mitigation activities for the reporting year as determined according to 
Sec.  99.32(a).
    (9) The quantity of methane emissions to be exempted due to the 
unreasonable delay for the reporting year calculated as specified in 
Sec.  99.32 and the method used to determine the quantity of methane 
emissions to be exempted (used Sec.  99.32(b)(1); used Sec.  
99.32(b)(2)(i); used Sec.  99.32(b)(2)(ii) with Kf based on 
volume; used Sec.  99.32(b)(2)(ii) with Kf based on time).
    (10) Information on all applicable local, state, and federal 
regulations regarding flaring emissions and the facility's compliance 
status for each.
    (11) For each permit relevant to the exemption, the name/type of 
permit, permitting agency, and a link to information on the permit 
(e.g., available through the permitting agency), if available.
    (c) Each submittal under this section shall be certified, signed, 
and submitted by the designated representative or any alternate 
designated representative of the WEC obligated party in accordance with 
this section and Sec.  3.10 of this chapter.


Sec.  99.32  How are the methane emissions caused by an unreasonable 
delay in environmental permitting of gathering or transmission 
infrastructure quantified?

    (a) Determine the time period associated with the emissions that 
occurred as a result of the eligible delay within the reporting year as 
specified in paragraphs (a)(1) and (2) of this section.
    (1) The start date of the emissions caused by the delay in the 
reporting year is the latter of January 1 of the reporting year, or the 
date on which emissions would have been avoided through commencement of 
the operation of the gathering or transmission infrastructure if the 
application to construct and/or operate the gathering or transmission 
infrastructure had been approved within a set period of months as 
specified in Sec.  99.31(b)(6).
    (2) The end time of the emissions caused by the delay in the 
reporting year is the earlier of December 31 of the reporting year or 
the date the emissions caused by the unreasonable delay ends because 
the infrastructure commenced operation.
    (b) For each well-pad or offshore platform at a WEC applicable 
facility

[[Page 5377]]

impacted by an unreasonable delay in environmental permitting of 
gathering or transmission infrastructure, you must calculate the 
emissions that occurred at the well-pad or offshore platform that were 
caused by the unreasonable delay according to paragraph (b)(1) or (2) 
of this section, as applicable.
    (1) If the unreasonable delay impacts the entire reporting year, 
and has resulted in the entire volume of flaring occurring from flare 
stacks, associated gas flaring, or offshore production flaring, then 
use the mass CH4 emissions, in mt CH4, as 
reported in Sec.  98.236(m)(8)(iii), (n)(10), and/or (s)(2) of this 
chapter, as applicable, for the individual flare(s) in the offshore 
petroleum and natural gas production industry segment and onshore 
petroleum gas production industry segment used to flare the increased 
volume of gas from methane emissions mitigation implementation 
associated with the unreasonable delay in environmental permitting of 
gathering or transmission infrastructure. If multiple flares are used 
to flare the increased volume of gas, sum the mass CH4 
emissions for each flare used to flare the increased volume of gas from 
methane emissions mitigation implementation to determine the cumulative 
emissions associated with the permitting delay.
    (2) If the unreasonable delay impacts only a portion of the 
reporting year or only a portion of the flaring emissions, determine 
the eligible emissions as specified in paragraph (b)(2)(i) or (ii) of 
this section, as applicable.
    (i) If you have records to calculate the mass CH4 
emissions from the flare(s) used to flare the increased volume of gas 
from methane emissions mitigation implementation associated with the 
unreasonable delay in environmental permitting of gathering or 
transmission according to the applicable methods in subpart W of this 
chapter for the specific time period eligible for the exemption, you 
must calculate the methane emissions for the specific time period 
eligible for the exemption from each flare used to flare the increased 
volume of gas from methane emissions mitigation implementation 
associated with the unreasonable delay. If multiple flares are used to 
flare the increased volume of gas, sum the mass CH4 
emissions for each flare calculated according to this paragraph to 
determine the cumulative emissions associated with the permitting 
delay.
    (ii) If you do not have records to calculate the mass 
CH4 emissions for the exemption period according to 
paragraph (b)(2)(i) of this section, then calculate the emissions that 
occurred at the offshore facility or onshore well-pad caused by the 
unreasonable delay using Equation C-1 of this section.
[GRAPHIC] [TIFF OMITTED] TP26JA24.022

Where:

EDelay,CH4 = Annual CH4 emissions associated 
with delay in permitting in the reporting year, mt CH4.
EMMFlare,CH4 = Annual CH4 emissions from the 
flare(s) used to flare increased volume of gas from methane 
emissions mitigation implementation reported in subpart W of this 
chapter, mt CH4.
Kf = Eligible timeframe adjustment factor to the 
CH4 emissions flaring emissions for partial year 
exemption period. If you have records of the volume of gas flared 
from the impacted flare(s) during the exemption period, use the 
ratio of the volume of gas flared during the exemption period to the 
total annual volume of gas flared from the impacted flare(s) to 
determine Kf; otherwise, use the ratio of hours in the 
exemption period to the total annual hours in the reporting year 
(8760 or, for leap years, 8784) to determine Kf.
Xf = Fraction of the flared emissions reported in subpart 
W of this chapter that occurred from the flare(s) due to the 
unreasonable delay. This fraction can be estimated based on company 
records of flare emissions prior to the unreasonable delay or 
through engineering calculations of flare volumes related to other 
sources vented to the flare(s).


Sec.  99.33  What are the recordkeeping requirements for methane 
emissions caused by an unreasonable delay in environmental permitting 
of gathering or transmission infrastructure?

    (a) For each communication the entity seeking the permit has had 
with the permitting authority regarding the permit application:
    (1) The date and type of communication.
    (2) The date of the facility's response to the communication.
    (3) Information on whether the facility's response included 
modification to the permit application.
    (b) Records of values used in the calculation of the emissions that 
occurred at the well-pad caused by the unreasonable delay.

Subpart D--Regulatory Compliance Exemption


Sec.  99.40  When does the regulatory compliance exemption come into 
effect, and under what conditions does the exemption cease to be in 
effect?

    (a) The requirements of this subpart only apply to a WEC applicable 
facility when the total facility applicable emissions for that WEC 
applicable facility as calculated in accordance with Sec.  99.21(a) 
exceed 0 mt CH4.
    (b) The requirements of Sec.  99.41 shall only be in effect when 
each of the following conditions are met:
    (1) A determination has been made by the Administrator that methane 
emissions standards and plans pursuant to subsections (b) and (d) of 
section 111 of the Act have been approved and are in effect in all 
States with respect to the applicable facilities; and
    (2) A determination has been made by the Administrator that the 
emissions reductions achieved by compliance with the requirements 
described in paragraph (b)(1) of this section will result in equivalent 
or greater emissions reductions on a nationwide basis as would be 
achieved by the proposed rule of the Administrator entitled `Standards 
of Performance for New, Reconstructed, and Modified Sources and 
Emissions Guidelines for Existing Sources: Oil and Natural Gas Sector 
Climate Review' (86 FR 63110; November 15, 2021), if such rule had been 
finalized and implemented.
    (c) At such time that the conditions specified in paragraphs (b)(1) 
and (2) of this section are met, the reporting requirements of Sec.  
99.41 shall come into effect beginning with the WEC filing due on the 
date specified in Sec.  99.5 in the calendar year following the 
calendar year in which the conditions were met. Imposition of the waste 
emission charge shall not be made on an applicable facility meeting the 
requirements for regulatory compliance exemption for methane emissions 
that occurred during the calendar year during which the conditions are 
met.
    (d) If any of the conditions in paragraph (b)(1) or (2) of this 
section cease to apply after the Administrator has made the 
determinations in paragraph (b)(1) and (2) of this section, the 
reporting requirements of Sec.  99.41 shall cease to be in effect 
beginning with the WEC filing due on the date specified in Sec.  99.5 
in the calendar year during which either of the conditions were no 
longer met.

[[Page 5378]]

Sec.  99.41  Which facilities qualify for the exemption for regulatory 
compliance?

    (a) The total facility applicable emissions for the WEC applicable 
facility as calculated in accordance with Sec.  99.21(a) or (d) must 
exceed 0 mt.
    (b) The WEC applicable facility must contain one or more affected 
facilities or one or more designated facilities.
    (c) At the WEC applicable facility, all affected facilities and all 
designated facilities located at this WEC applicable facility, must 
have no deviations or violations with the methane emissions 
requirements of part 60 of this chapter and the methane emissions 
requirements requirements of an applicable approved state, Tribal, or 
Federal plan in part 62 of this chapter, including all applicable 
emission standard, work practice, monitoring, reporting, and 
recordkeeping requirements.


Sec.  99.42  What are the reporting requirements for the exemption for 
regulatory compliance?

    (a) A facility eligible for the regulatory compliance exemption 
that meets the criteria described in Sec.  99.41 shall include 
information as described in paragraph (b) of this section. A facility 
that meets the criteria described in Sec.  99.41(a) and (b) but is not 
eligible for the exemption because it does not meet the criteria in 
Sec.  99.41(c) shall include information as described in paragraph (d) 
of this section. The regulatory compliance exemption information shall 
be submitted as described in Sec.  99.7.
    (b) A facility meeting the criteria in Sec.  99.41 must report all 
of the information specified in paragraphs (b) of this section, as 
applicable.
    (1) For each WEC applicable facility, an assertion that the 
facility meets all of the eligibility criteria in Sec.  99.41.
    (2) The ICIS-AIR ID (or Facility Registry Service (FRS) ID if the 
ICIS-AIR ID is not available) and EPA Registry ID from CEDRI associated 
with each affected facility and designated facility located at the WEC 
applicable facility.
    (3) If a report, or reports, prepared and submitted in accordance 
with part 60 of this chapter, or an applicable approved state, Tribal, 
or Federal plan under part 62 of this chapter that implements the 
emission guidelines contained in part 60 of this chapter, cover the 
complete reporting year (i.e., January 1 through December 31, 
inclusive), then submit as attachment(s) the applicable report(s).
    (4) If a report, or reports, prepared and submitted in accordance 
with part 60 of this chapter, or an applicable approved state, Tribal, 
or Federal plan under part 62 of this chapter that implements the 
emission guidelines contained in part 60 of this chapter, does not 
cover the complete reporting year (i.e., January 1 through December 31, 
inclusive), then submit as attachment(s) the applicable report(s).
    (c) If, pursuant to paragraph (b)(4) of this section, you are 
unable to provide an annual report covering the entire reporting year 
at the time of the initial submittal specified in Sec.  99.5, you must 
provide a revised WEC filing on or before such time that an annual 
report covering the entire reporting year is required to be submitted 
under the applicable requirements of part 60 of this chapter or an 
applicable approved state, Tribal, or Federal plan in part 62 of this 
chapter. This requirement also applies in the case where the initial 
WEC filing contains an annual report covering only a portion of the 
reporting year. On or before such time that an annual report is due 
under the applicable requirements of part 60 of this chapter or an 
applicable approved state, Tribal, or Federal plan in part 62 of this 
chapter for the portion of the reporting year for which a previously 
submitted report does not cover, you must provide a revised WEC filing 
including the subsequent annual report. The resubmission of the revised 
WEC filing shall be considered timely under this paragraph if it is 
made on or before the date that the annual report is due under the 
applicable requirements of part 60 of this chapter or an applicable 
approved state, Tribal, or Federal plan in part 62 of this chapter. In 
such cases where a newly available report indicates one or more 
deviations or violations from applicable methane emissions requirements 
that were not previously indicated in the WEC filing for the reporting 
year (i.e., the WEC applicable facility would no longer qualify for the 
regulatory compliance exemption), a WEC applicable facility would no 
longer be subject the reporting requirements in Sec.  99.42(b) and 
would become subject to the reporting requirements in Sec.  99.42(d) in 
the revised WEC filing.
    (d) If least one of the affected facilities subject to the 
requirements of part 60 of this chapter or designated facilities 
subject to the requirements of an applicable approved state, Tribal, or 
Federal plan in part 62 of this chapter that is contained within your 
WEC applicable facility has a deviation or violation from its 
applicable methane emissions requirements (i.e., does not meet the 
criteria in Sec.  99.41(c)), provide a copy of one report, prepared and 
submitted in accordance with part 60 of this chapter, or an applicable 
approved state, Tribal, or Federal plan under part 62 of this chapter 
that implements the emission guidelines contained in part 60 of this 
chapter, that demonstrates that the affected facility or designated 
facility were not in compliance.
    (e) A WEC applicable facility's eligibility for the regulatory 
compliance exemption pursuant to this subpart does not constitute a 
determination of compliance for part 60 of this chapter, or an 
applicable approved state, Tribal, or Federal plan under part 62 of 
this chapter that implements the emission guidelines contained in part 
60 of this chapter, for any affected facility or designated facility 
present at the applicable facility.
    (f) A WEC applicable facility's eligibility for the regulatory 
compliance exemption during a given reporting year does not preclude 
reassessment of applicable waste emissions charges for that applicable 
facility upon discovery by the Administrator or a delegated authority 
of any violation of the methane emissions requirements pursuant to part 
60 of this chapter, or an applicable approved state, Tribal, or Federal 
plan under part 62 of this chapter that implements the emission 
guidelines contained in part 60 of this chapter, for the affected 
facilities or designated facilities present at the applicable facility.

Subpart E--Exemption for Permanently Shut-in and Plugged Wells


Sec.  99.50  Which facilities qualify for the exemption of emissions 
from permanently shut-in and plugged wells?

    (a) The total facility applicable emissions for the WEC applicable 
facility containing permanently shut-in and plugged wells must exceed 0 
mt as calculated in accordance with Sec.  99.21(a).
    (b) This exemption is applicable to WEC applicable facilities in 
the offshore petroleum and natural gas production or onshore petroleum 
and natural gas production industry segment as defined in Sec.  99.2 
that permanently shut-in and plugged well(s) during the reporting year. 
For the purposes of applying this exemption, a permanently shut-in and 
plugged well is one that has been permanently sealed, following all 
applicable local, state, or federal regulations in the jurisdiction 
where the well is located, to prevent any potential future leakage of 
oil, gas, or formation water into shallow sources of potable water, 
onto the surface, or into the atmosphere. Site reclamation following 
placement of a metal plate or cap is not required to be completed for 
the well to

[[Page 5379]]

be considered permanently shut-in and plugged for the purposes of this 
part.


Sec.  99.51  What are the reporting requirements for the exemption for 
wells that were permanently shut-in and plugged?

    (a) Report the following information for each well at a WEC 
applicable facility, in the offshore petroleum and natural gas 
production or onshore petroleum and natural gas production industry 
segment, that was permanently shut-in and plugged in the reporting 
year.
    (1) Well identification (ID) number as reported in part 98, subpart 
W of this chapter.
    (2) Date the well was permanently shut-in and plugged, which for 
the purposes of this exemption, is the date when welding or cementing 
of a metal plate or cap onto the casing end was completed.
    (3) The statutory citation for each applicable state, local, and 
federal regulation stipulating requirements that were applicable to the 
closure of the permanently shut-in and plugged well.
    (4) The equation used to calculate equipment leak emissions 
attributable to the well (i.e., Equation E-2A or E-2B of this subpart).
    (5) The emissions attributable to the well calculated using 
Equation E-1, E-3, or E-4 of this subpart, as applicable.
    (b) The total quantity of methane emissions attributable to all 
wells that were permanently shut-in and plugged at a WEC applicable 
facility, in the offshore petroleum and natural gas production or 
onshore petroleum and natural gas production industry segment, during 
the reporting year, calculated using Equation E-5 of this subpart.


Sec.  99.52  How are the net emissions attributable to all wells at a 
WEC applicable facility that were permanently shut-in and plugged in 
the reporting year quantified?

    (a) For the purposes of this section, the following source types 
(as specified in part 98, subpart W of this chapter) constitute 
emissions directly attributable to an offshore petroleum and natural 
gas production or onshore petroleum and natural gas production well:
    (1) Wellhead equipment leaks.
    (2) Liquids unloading.
    (3) Workovers with hydraulic fracturing.
    (4) Workovers without hydraulic fracturing.
    (b) Calculate the annual emissions attributable to each well that 
was permanently shut-in and plugged during the reporting year and 
included in the submittal pursuant to Sec.  99.51 using Equations E-1, 
E-3 or E-4 of this section, as applicable.
    (1) For onshore petroleum and natural gas production wells that are 
part of a WEC applicable facility that are permanently shut-in and 
plugged in reporting years 2025 and later:
    (i) Equation E-1 of this section must be used to quantify the 
methane emissions directly attributable to each permanently shut-in and 
plugged well.
[GRAPHIC] [TIFF OMITTED] TP26JA24.023

Where:

EPW,CH4 = The annual quantity of methane emissions 
directly attributable to an individual well that was permanently 
shut-in and plugged during the reporting year in accordance with all 
applicable closure requirements at a WEC applicable facility, mt 
CH4.
ELeaks,CH4 = The annual quantity of methane emissions 
attributable to the well from wellhead equipment leaks as calculated 
using Equation E-2A or E-2B of this section, as applicable, for the 
reporting year, mt CH4.
ELU,CH4 = The annual quantity of methane emissions 
attributable to the well from liquids unloading as reported pursuant 
to proposed Sec.  98.236(f)(1)(x) or (f)(2)(viii) of this chapter, 
as applicable, for the reporting year, mt CH4.
EWwHF,CH4 = The quantity of methane emissions 
attributable to the well from workovers with hydraulic fracturing as 
reported pursuant to proposed Sec.  98.236(g)(9) of this chapter for 
the reporting year, mt CH4.
EWwoHF,CH4 = The quantity of methane emissions 
attributable to the well from workovers without hydraulic fracturing 
and without flaring as reported pursuant to proposed Sec.  
98.236(h)(3)(iv) of this chapter for the reporting year, mt 
CH4.

    (ii) If equipment leak surveys were used to quantify methane 
emissions from the permanently shut-in and plugged well and reported 
pursuant to Sec.  98.236(q) of this chapter in the part 98 report for a 
WEC applicable facility, Equation E-2A of this section must be used to 
calculate ELeaks,CH4.
[GRAPHIC] [TIFF OMITTED] TP26JA24.004

Where:

ELeaks,CH4 = The annual quantity of methane emissions 
attributable to the well from wellhead equipment leaks as reported 
pursuant to Sec.  98.236(q) of this chapter for the reporting year, 
mt CH4.
p = Component type as specified in proposed Sec.  98.233(q)(2)(iii) 
of this chapter.
Np = The number of component types with detected leaks at 
the well.
EFp = The leaker emission factor for component ``p'' as 
specified in proposed Sec.  98.233(q)(2)(iii) of this chapter, scf 
whole gas/hour/component.
MCH4 = The mole fraction of CH4 in produced 
gas for the sub-basin associated with the well, as reported pursuant 
to proposed Sec.  98.236(aa)(1)(ii)(I), unitless.
xp = The total number of specific components of type 
``p'' detected as leaking at the permanently shut-in and plugged 
well in any leak survey during the year. A component found leaking 
in two or more surveys during the year is counted as one leaking 
component.
Tp,z = The total time the surveyed component ``z'' of 
component type ``p'' was assumed to be leaking. If one leak 
detection survey is conducted in the calendar year, assume the 
component was leaking from the beginning of the reporting year until 
the date the well was plugged in accordance with Sec.  99.51(a)(2), 
hours; assume a component found leaking in the last survey of the 
year was leaking from the preceding survey through the date the well 
was plugged in accordance with Sec.  99.51(a)(2), hours; assume a 
component found leaking in a survey between the first and last 
surveys of the year was leaking since the preceding survey until the 
date the well was

[[Page 5380]]

plugged in accordance with Sec.  99.51(a)(2), hours; and sum times 
for all leaking periods. For each leaking component, account for 
time the component was not operational (i.e., not operating under 
pressure) using an engineering estimate based on best available 
data.
k = The factor to adjust for undetected leaks by respective leak 
detection method, where k equals 1.25 for the methods in proposed 
Sec.  98.234 (a)(1), (3) and (5) of this chapter; k equals 1.55 for 
the method in proposed Sec.  98.234(a)(2)(i) of this chapter; and k 
equals 1.27 for the method in proposed Sec.  98.234(a)(2)(ii) of 
this chapter. Select the factor for the leak detection method used 
for the permanently shut-in and plugged well, unitless.
[rho]CH4 = Density of methane, 0.0192 mt/Mscf.
10-3 = Conversion factor from scf to Mscf.

    (iii) If equipment leaks by population count were used to quantify 
methane emission from the permanently shut-in and plugged well and 
reported pursuant to Sec.  98.236(r) of this chapter in the part 98 
report for a WEC applicable facility, Equation E-2B of this section 
must be used to calculate ELeaks,CH4.
[GRAPHIC] [TIFF OMITTED] TP26JA24.024

Where:

ELeaks,CH4 = The annual quantity of methane emissions 
attributable to the well from wellhead equipment leaks as reported 
pursuant to Sec.  98.236(r) of this chapter for the reporting year, 
mt CH4.
EFwh = The population emission factor for wellheads, as 
listed in proposed Table W-1 of subpart W of part 98 of this 
chapter, scf whole gas/hour/wellhead.
MCH4 = The mole fraction of CH4 in produced 
gas for the sub-basin associated with the well as reported pursuant 
to proposed Sec.  98.236(aa)(1)(ii)(I) of this chapter, unitless.
T = The total time that has elapsed from the beginning of the 
reporting year until the date the well was plugged in accordance 
with Sec.  99.51(a)(2), hours.
PCH4 = Density of methane, 0.0192 mt/Mscf.
10-3 = Conversion factor from scf to Mscf.

    (2) For onshore petroleum and natural gas production wells that are 
part of a WEC applicable facility that are permanently shut-in and 
plugged in reporting year 2024, Equation E-3 of this section must be 
used to quantify the methane emissions attributable to the well:
[GRAPHIC] [TIFF OMITTED] TP26JA24.001

Where:

EPW,CH4 = The annual quantity of methane emissions 
attributable to an individual well that was permanently shut-in and 
plugged during the reporting year in accordance with all applicable 
closure requirements at a WEC applicable facility, mt 
CH4.
ELkQ = The WEC applicable facility total annual quantity 
of methane emissions from equipment leaks reported pursuant to 
proposed Sec.  98.236(q)(2)(ix) of this chapter for the reporting 
year, mt CH4.
ELkR = The WEC applicable facility total annual quantity 
of methane emissions from equipment leaks reported pursuant to 
proposed Sec.  98.236(r)(1)(vi) of this chapter for the reporting 
year, mt CH4.
ELU = The WEC applicable facility total annual quantity 
of methane emissions from liquids unloading as reported pursuant to 
proposed Sec. Sec.  98.236(f)(1)(x) and (f)(2)(viii) of this chapter 
for the reporting year, mt CH4.
EWwHF = The WEC applicable facility total annual quantity 
of methane emissions from workovers with hydraulic fracturing as 
reported pursuant to proposed Sec.  98.236(g)(9) of this chapter for 
the reporting year, mt CH4.
EWwoHF = The WEC applicable facility total annual 
quantity of methane emissions from workovers without hydraulic 
fracturing as reported pursuant to proposed Sec.  98.236(h)(3)(iv) 
of this chapter for the reporting year, mt CH4.
Qng,PW = The total annual quantity of natural gas that is 
produced and sent to sale from the well in the reporting year, as 
reported pursuant to proposed Sec.  98.236(aa)(1)(iii)(C) of this 
chapter, in thousand standard cubic feet.
6 = Conversion factor from thousand standard cubic feet of natural 
gas to barrel of oil equivalent.
Qoil,PW = The total quantity of crude oil that is 
produced and sent to sale from the well in the reporting year, as 
reported pursuant to proposed Sec.  98.236(aa)(1)(iii)(D) of this 
chapter, in barrels.
Qcond,PW = The total quantity of condensate that is 
produced and sent to sale from the well in the reporting year, as 
reported pursuant to proposed Sec.  98.236(aa)(1)(iii)(E) of this 
chapter, in barrels.
Qng,WAF = The total quantity of natural gas that is 
produced and sent to sale from the WEC applicable facility in the 
reporting year, as reported pursuant to proposed Sec.  
98.236(aa)(1)(i)(B) of this chapter, in thousand standard cubic 
feet.
Qoil,WAF = The total quantity of crude oil that is 
produced and sent to sale from the WEC applicable facility in the 
reporting year, as reported pursuant to proposed Sec.  
98.236(aa)(1)(i)(C) of this chapter, in barrels.
Qcond,WAF = The total quantity of condensate that is 
produced and sent to sale from the WEC applicable facility in the 
reporting year, as reported pursuant to proposed Sec.  
98.236(aa)(1)(i)(D) of this chapter, in barrels.

    (3) For offshore petroleum and natural gas production wells that 
are part of a WEC applicable facility that are permanently shut-in and 
plugged in any reporting year, Equation E-4 of this section must be 
used to quantify the methane emissions attributable to the well.
[GRAPHIC] [TIFF OMITTED] TP26JA24.002


[[Page 5381]]


Where:

EPW,CH4 = The annual quantity of methane emissions 
attributable to an individual well that was permanently shut-in and 
plugged during the reporting year in accordance with all applicable 
closure requirements at a WEC applicable facility, mt 
CH4.
ELeaks,CH4 = The WEC applicable facility total annual 
quantity of methane emissions from non-compressor component level 
fugitives (i.e., equipment leaks) reported pursuant to proposed 
Sec.  98.236(s)(3)(ii) of this chapter for the reporting year, mt 
CH4.
Qng,PW = The total annual quantity of natural gas that is 
produced and sent to sale from the well in the reporting year as 
reported pursuant to proposed Sec.  98.236(aa)(2)(iv) of this 
chapter, in thousand scf.
6 = Conversion factor from thousand standard cubic feet of natural 
gas to barrel of oil equivalent.
Qoil,PW = The total quantity of crude oil that is 
produced and sent to sale from the well in the reporting year, as 
reported pursuant to proposed Sec.  98.236(aa)(2)(v) of this 
chapter, in barrels.
Qcond,PW = The total quantity of condensate that is 
produced and sent to sale from the well in the reporting year, as 
reported pursuant to proposed Sec.  98.236(aa)(2)(vi) of this 
chapter, in barrels.
Qng,WAF = The total quantity of natural gas that is 
produced and sent to sale from the WEC applicable facility in the 
reporting year, as reported pursuant to proposed Sec.  
98.236(aa)(2)(i) of this chapter, in thousand scf.
Qoil,WAF = The total quantity of crude oil that is 
produced and sent to sale from the WEC applicable facility in the 
reporting year, as reported pursuant to proposed Sec.  
98.236(aa)(2)(ii) of this chapter, in barrels.
Qcond,WAF = The total quantity of condensate that is 
produced and sent to sale from the WEC applicable facility in the 
reporting year, as reported pursuant to proposed Sec.  
98.236(aa)(2)(iii) of this chapter, in barrels.

    (c) Calculate the total emissions attributable to all wells 
included in the submittal received pursuant to Sec.  99.51 using 
Equation E-5 of this section:
[GRAPHIC] [TIFF OMITTED] TP26JA24.006

EPlug,CH4 = The total quantity of annual methane 
emissions, as determined in subpart E of this part, at the WEC 
applicable facility in the onshore petroleum and natural gas 
production and offshore petroleum and natural gas production 
industry segments, attributable to all wells that were permanently 
shut-in and plugged during the reporting year in accordance with all 
applicable closure requirements, mt CH4.
EPW,CH4 = The annual quantity of methane emissions 
attributable to a well ``j'' that was permanently shut-in and 
plugged during the reporting year in accordance with all applicable 
closure requirements at a WEC applicable facility calculated using 
Equation E-1, E-3, or E-4 of this section, as applicable.
N = Total number of wells that were permanently shut-in and plugged 
during the reporting year in accordance with all applicable closure 
requirements at a WEC applicable facility.

[FR Doc. 2024-00938 Filed 1-25-24; 8:45 am]
BILLING CODE 6560-50-P