Sec.   98.236(aa)(3)(i)...........  Quantity of natural gas     Sec.   98.406(a)(3)..  Annual volume of natural
                                     received.                                          gas received for
                                                                                processing.
Sec.   98.236(aa)(3)(iii).........  Cumulative quantity of all  Sec.   98.406(a)(2)    Annual quantity of each
                                     NGLs (bulk and              Sec.                   NGL product received and
                                     fractionated) received.     98.406(a)(4)(i).       annual quantities of y-
                                                                                grade, o-grade and other
                                                                                bulk NGLs received.
Sec.   98.236(aa)(3)(iv)..........  Cumulative quantity of all  Sec.   98.406(a)(1)    Annual quantity of each
                                     NGLs (bulk and              Sec.                   NGL product supplied and
                                     fractionated) leaving.      98.406(a)(4)(ii).      annual quantities of y-
                                                                                grade, o-grade and other
                                                                                bulk NGLs supplied.
----------------------------------------------------------------------------------------------------------------

    The EPA is also proposing to remove the reporting elements for the
volume of natural gas used for operational purposes and natural gas
stolen specified in 40 CFR 98.236(aa)(9)(vi) and (vii). These reporting
elements are unique to subpart W, require additional burden to
estimate, and have not been used for the EPA's analyses of the subpart
W data. As a result of proposing to remove all of the 40 CFR
98.236(aa)(9) data elements for the reasons explained in this section
of this preamble, the EPA proposes to reserve paragraph 40 CFR
98.236(aa)(9).
3. Onshore Natural Gas Transmission Pipeline Storage Throughputs
    Similar to Natural Gas Distribution facilities, Onshore Natural Gas
Transmission Pipeline facilities are currently required to report five
throughput volumes under subpart W, as specified in existing 40 CFR
98.236(aa)(11). These five data reporting elements include: the
quantity of natural gas received at all custody transfer stations; the
quantity of natural gas withdrawn from in-system storage; the quantity
of gas added to in-system storage; the quantity of gas transferred to
third parties; and the quantity of gas consumed by the transmission
pipeline facility for operational purposes. As noted in section III.U.1
of this preamble, the EPA has received stakeholder feedback on the
reporting elements for Natural Gas Distribution facilities, including
questions submitted to the GHGRP Help Desk, regarding the term ``in-
system storage.'' Although the questions were specific to Natural Gas
Distribution facilities, the term ``in-system storage'' is also
included in the throughput reporting elements for Onshore Natural Gas
Transmission Pipeline facilities at existing 40 CFR 98.236(aa)(11)(ii)
and (iii). After consideration of the stakeholder feedback, the EPA is
proposing to revise these provisions to better characterize the
existing term ``in-system.'' Specifically, we are proposing to amend 40
CFR 98.236(aa)(11)(ii) and (iii) to replace the term ``in-system'' with
clarifying language that specifies withdrawals/additions of natural gas
from storage are referring to Underground Natural Gas Storage and LNG
Storage facilities that are owned and operated by the onshore natural
gas transmission pipeline owner or operator that do not report under
subpart W as direct emitters themselves. These amendments are expected
to improve data quality consistent with section II.D of this preamble.

V. Other Proposed Minor Revisions or Clarifications

    See Table 4 of this preamble for the miscellaneous minor technical
corrections not previously described in this preamble that we are
proposing throughout subpart W, consistent with section II.D of this
preamble.

          Table 4--Proposed Technical Corrections to Subpart W
------------------------------------------------------------------------
       Section (40 CFR)            Description of proposed amendment
------------------------------------------------------------------------
98.230(a)(2).................  Revise the instance of ``well pad'' to
                                read ``well-pad'' to correct
                                inconsistency in the term.
98.230(a)(9).................  Remove the ``)'' after ``GOR'' to correct
                                a typographical error.
98.232 introductory text.....  Add reference to paragraph (l) of this
                                section to clarify that annual reports
                                must include the information specified
                                in paragraph (l) if applicable.
98.232(c)(17), (d)(5) and      Revise the instances of ``acid gas
 (j)(3).                        removal vents'' to read ``acid gas
                                removal unit vents'' for consistency
                                with the defined term ``Acid gas removal
                                unit (AGR)'' in 40 CFR 98.238.
98.233(d)....................  Revise the instances of ``AGR unit'' to
                                read ``AGR'' for consistency with the
                                defined term ``Acid gas removal unit
                                (AGR)'' in 40 CFR 98.238.
98.233(e)(1)(x),               Add ``at the absorber inlet'' to the end
 98.236(e)(1)(xi) and (xii).    of the paragraph to clarify the location
                                for the wet natural gas temperature and
                                pressure to be used for modeling.
98.233(j), 98.236(j).........  Revise the instances of ``oil,'' ``oil/
                                condensate,'' and ``liquid'' to read
                                ``hydrocarbon liquids'' for consistency
                                with the requirement in 40 CFR 98.233(j)
                                to calculate emissions from
                                ``atmospheric pressure fixed roof
                                storage tanks receiving hydrocarbon
                                produced liquids,'' as noted in the 2015
                                amendments to subpart W (80 FR 64272,
                                October 22, 2015).
98.233(k)....................  Revise the introductory sentence in this
                                section to specify that 40 CFR 98.233(k)
                                does not apply to condensate storage
                                tanks that route emissions to flares or
                                other controls for consistency with
                                proposed amendment that would move
                                procedures for calculating flared
                                emissions from 40 CFR 98.233(k) to 40
                                CFR 98.233(n).

98.233(n)(5).................  Correct the cross reference in the
                                definition of the equation variable
                                ``Yj'' from paragraph (n)(1) to (n)(2).
98.233(o) introductory text    Move the last sentence in each paragraph
 and (p) introductory text.     to be the second sentence to clarify
                                that the calculation methodology for
                                compressors routed to flares,
                                combustion, or vapor recovery systems
                                apply to all industry segments.
98.233(o) introductory text    Revise the instances of ``vapor
 and (p) introductory text,     recovery'' to read ``vapor recovery
 236(o)(2)(ii) and (p)(2)(ii).  system'' to correct inconsistency in the
                                term.
98.233(p)(1)(i)..............  Correct the internal cross reference from
                                paragraph (o) to paragraph (p).
98.233(p)(4)(ii)(C)..........  Add missing ``in'' to read ``according to
                                methods set forth in Sec.   98.234(d).''
98.233(r) introductory text..  Revise the instance of ``CH'' in the
                                third sentence to read ``CH4'' to
                                correct a typographical error.
98.233(r), equations W-32A     Correct the cross reference in the
 and W-32B.                     definition of the equation variable
                                ``Es,MR,i'' and the equation variable
                                ``CountMR'' from paragraph (q)(9) to
                                (q)(2)(xi) or (q)(3)(vii)(B).
98.233(r)(6)(ii).............  Add reference to components listed in 40
                                CFR 98.232(i)(3), for consistency with
                                proposed amendments to 40 CFR
                                98.233(r)(6)(i).
98.233(t)(2).................  Revise the definition of equation
                                variable ``Za'' to include the sentence
                                following the definition of that
                                variable to correct a typographical
                                error.
98.233(u)(2)(ii).............  Format the heading to be in italicized
                                text.
98.233(z)....................  Revise the instances of ``high heat
                                value'' to read ``higher heating value''
                                to correct inconsistency in the term.
98.233(z), equations W-39A     Remove unnecessary ``constituent'' from
 and W-39B.                     ``CO2 constituent'' and ``methane
                                constituent'' and remove ``gas'' from
                                ``gas hydrocarbon constituent.'' Add
                                missing ``the'' to read ``to the
                                combustion unit'' in several variable
                                definitions.
98.234(e)....................  Renumber the Peng Robinson equation of
                                state from equation W-41 to equation W-
                                46 to provide space for five new
                                equations related to new source types in
                                proposed 40 CFR 98.233(dd) and (ee).
98.234(f)....................  Remove and reserve paragraph for
                                provisions for best available monitoring
                                methods for RY2015, as reports for that
                                reporting year can no longer be
                                submitted to the EPA.
98.234(g)....................  Remove and reserve paragraph for
                                provisions for best available monitoring
                                methods for RY2016, as reports for that
                                reporting year can no longer be
                                submitted to the EPA.
98.236 introductory text.....  Add missing ``than'' to read ``report gas
                                volumes at standard conditions rather
                                than the gas volumes at actual
                                conditions''
98.236(c)(5)(i) through (iii)  Edits to explicitly state that the
                                reporting requirements in this section
                                apply to pneumatic pumps that are vented
                                direct to atmosphere and for which
                                emissions are calculated using the
                                default emission factor (Calculation
                                Method 3).
                               Revise ``operational'' to ``pumping
                                liquid'' in the description of the
                                reported time element in 98.236(c)(5)(i)
                                to be consistent with the proposed
                                change described in section III.E.3 of
                                this preamble for Calculation Method 2.
98.236(d)(2)(iii)(B).........  Revise ``natural gas flow rate'' to read
                                ``natural gas feed flow rate'' for
                                consistency with the parameters listed
                                in 40 CFR 98.233(d)(4)(i).
98.236(e)(1) and (2).........  Revise the instances of ``vented to'' a
                                control device, vapor recovery, or a
                                flare to read ``routed to'' to correct
                                inconsistency in the phrases ``vented
                                to'' and ``routed to.''
                               Revise the instances of ``vapor recovery
                                device'' to read ``vapor recovery
                                system'' to correct inconsistency in the
                                term.
98.236(j)(2).................  Clarify that the reported information in
                                paragraphs (j)(1)(i) through (xvi)
                                should only include those atmospheric
                                storage tanks with emissions calculated
                                using Calculation Method 3.
98.236(k)(1)(iii)............  Correct the internal cross reference from
                                ``Sec.   98.233(k)(2)'' to ``Sec.
                                98.233(k)(1).''
98.236(k)(2).................  Add a cross reference to Sec.
                                98.233(k)(2) and revise sentence to
                                specify that the reported method used to
                                measure leak rates should be one
                                provided in that section.
98.236(l)(1), (2), (3), and    Revise the instances of ``vented to a
 (4) introductory text.         flare'' to read ``routed to a flare'' to
                                correct inconsistency in the phrases
                                ``vented to'' and ``routed to.''
98.236(p)(3)(ii).............  Add a missing period at the end of the
                                sentence.
98.236(bb)...................  Clarify that reporting for missing data
                                procedures includes the procedures used
                                to substitute an unavailable value of a
                                parameter (per 40 CFR 98.235(h)).
98.236(cc)...................  Correct the cross references from
                                paragraph (l)(1)(iv), (l)(2)(iv),
                                (l)(3)(iii), and (l)(4)(iii) to
                                (l)(1)(v), (l)(2)(v), (l)(3)(iv), and
                                (l)(4)(iv), respectively.
98.238.......................  Remove the second definition of
                                ``Facility with respect to natural gas
                                distribution for purposes of reporting
                                under this subpart and for the
                                corresponding subpart A requirements''
                                to eliminate an inadvertent identical
                                duplicative definition.
Tables W-1 through W-7 to      Replace Tables W-1 through W-7 with new
 subpart W of part 98.          Tables W-1 through W-6 to reorganize and
                                consolidate the emission factor tables
                                so that there are separate tables by
                                pollutant (whole gas, THC, and CH4) and
                                by type of factor (population and leaker
                                emission factors). Update cross
                                references to these tables accordingly
                                throughout subpart W.
------------------------------------------------------------------------

IV. Schedule for the Proposed Amendments

    The EPA is planning to consider the comments on these proposed
changes, and, if any of the proposed amendments are finalized, to
respond to the comments and promulgate any amendments by August 16,
2024.\129\ We

are proposing that these amendments would become effective on January
1, 2025, and that reporters would implement the majority of the changes
beginning with reports prepared for RY2025 and submitted March 31,
2026. The exception is the proposed reporting of the quantities of
natural gas, crude oil, and condensate produced that is sent to sale in
the calendar year for each well permanently shut-in and plugged
(proposed 40 CFR 98.236(aa)(1)(iii)(C) through (E) and proposed 40 CFR
98.236(aa)(2)(iv) through (vi)); those provisions would become
effective on January 1, 2025 and reporters would include that
information in their reports prepared for RY2024 and submitted March
31, 2025. The submission date for RY2025 reports is over a year after
we expect a final rule based on this proposal to be finalized, if
finalized, thus providing a reasonable period for reporters to adjust
to any finalized amendments. The proposed effective date would also
allow ample time for the EPA to implement the changes into e-GGRT.
---------------------------------------------------------------------------

    \129\ Section 136(h) of the CAA requires subpart W to be revised
as specified in that provision ``not later than 2 years after the
date of enactment of this section.'' The section was enacted via
Public Law No: 117-169 on August 16, 2022.
---------------------------------------------------------------------------

    We are likewise proposing that the proposed CBI determinations
discussed in section VI of this preamble would become effective on
January 1, 2025. The majority of the determinations are for new or
revised data elements that would be included in annual GHG reports
prepared for RY2025 and submitted March 31, 2026. The determinations
related to the reporting of the quantities of natural gas, crude oil,
and condensate produced that is sent to sale in the calendar year for
each well permanently shut-in and plugged would apply the first year
that data is collected (i.e., RY2024 data submitted on or before March
31, 2025). Finally, there is one circumstance, discussed in detail in
section V of this preamble, where the proposed determination covers
data included in annual GHG reports submitted for prior years. In all
cases, the proposed determinations for the data that the EPA has
already received for these prior years or receives going forward for
any reporting year would become effective on January 1, 2025.

V. Proposed Confidentiality and Reporting Determinations for Certain
Data Reporting Elements

A. Overview and Background

    In this action we are proposing confidentiality determinations for
new or substantially revised data elements that would be collected
under the proposed rule amendments.
1. Background on EPA's Treatment of Data Collected Under Part 98
    Following proposal of part 98 (74 FR 16448, April 10, 2009), the
EPA received comments addressing the issue of whether certain data
could be entitled to confidential treatment. In response to these
comments, the EPA stated in the preamble to the 2009 Final Rule (74 FR
56387, October 30, 2009) that through a notice and comment process, we
would establish those data elements that are entitled to confidential
treatment. This proposal is one of a series of rules dealing with
confidentiality determinations for data reported under part 98,
including subpart C (General Stationary Fuel Combustion) and W
(Petroleum and Natural Gas Systems).
     75 FR 39094, July 7, 2010. Describes the data categories
and category-based determinations the EPA developed for the part 98
data elements.
     76 FR 30782, May 26, 2011; hereafter referred to as the
``2011 Final CBI Rule.'' Assigned data elements to data categories and
published the final CBI determinations for the data elements in 34 part
98 subparts, except for those data elements that were assigned to the
``Inputs to Emission Equations'' data category.
     77 FR 48072, August 13, 2012. Finalized confidentiality
determinations for data elements reported under nine subparts,
including subpart W, except for those data elements that are ``inputs
to emission equations''.
     78 FR 69337, November 29, 2013. Finalized determinations
for new and revised data elements in 15 subparts, including subpart C,
except for those data elements that are ``inputs to emission
equations''.
     79 FR 63750, October 24, 2014. Revised recordkeeping and
reporting requirements for ``inputs to emission equations'' for 23
subparts and finalized confidentiality determinations for new data
elements in 11 subparts, including subpart W.
     79 FR 70352, November 25, 2014. Finalized confidentiality
determinations for new and substantially revised data elements in
subpart W.
     80 FR 64262, October 22, 2015. Finalized confidentiality
determinations for new data elements in subpart W.
     81 FR 86490, November 30, 2016. Finalized confidentiality
determinations for new or substantially revised data elements in
subpart W.
     81 FR 89188, December 9, 2016. Finalized confidentiality
determinations for new or substantially revised data elements in 18
subparts, including subpart C.
     87 FR 36920, June 21, 2022. Describes the EPA's revised
approach to assessing data in response to Food Marketing Institute v.
Argus Leader Media, 139 S. Ct. 2356 (2019) (hereafter referred to as
Argus Leader).\130\
---------------------------------------------------------------------------

    \130\ See Docket Id. No. EPA-HQ-OAR-2023-0234.
---------------------------------------------------------------------------

    To support the proposed amendments to part 98 described in section
III of this preamble, we are proposing confidentiality determinations
or ``emission data'' designations, in keeping with our existing
approach (see section V.B.1 of this preamble), for the following:
     New or substantially revised reporting requirements (i.e.,
the proposed change requires additional or different data to be
reported);
     Existing reporting requirements for which the EPA did not
previously finalize a confidentiality determination or ``emission
data'' designation.
    Further, we propose to designate certain new or substantially
revised data elements as ``inputs to emission equations'' falling
within the definition of ``emission data.'' For each element that we
propose would fall in this category, we further propose whether the
data element would be directly reported to the EPA or whether it would
be entered into e-GGRT's Inputs Verification Tool (IVT) (see section
V.C of this preamble for a discussion of ``inputs to emission
equations'').
2. Summary of Data Elements Affected by the Proposed Amendments to Part
98
    Table 5 of this preamble provides the number of affected data
elements and the affected subparts for each of these proposed actions.

  Table 5--Summary of Proposed Actions Related to Data Confidentiality
------------------------------------------------------------------------
  Proposed actions related to data    Number of data
           confidentiality             elements \a\       Subpart(s)
------------------------------------------------------------------------
New or substantially revised                     522  C, W
 reporting requirements for which
 the EPA is proposing a
 confidentiality determination or
 ``emission data'' designation.
Existing reporting requirements for                1  W
 which the EPA is proposing a
 confidentiality determination or
 ``emission data'' designation
 because the EPA did not previously
 make a confidentiality
 determination or ``emission data''
 designation.
New or substantially revised                     162  W
 reporting requirements that the EPA
 is proposing be designated as
 ``inputs to emission equations''
 and for which the EPA is proposing
 reporting determinations.
------------------------------------------------------------------------
\a\ These data elements are individually listed in the memoranda: (1)
  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 (2) Proposed
  Reporting Determinations for Data Elements Assigned to the Inputs to
  Emission Equations Data Category in Proposed Revisions to the
  Greenhouse Gas Reporting Rule for Petroleum and Natural Gas Systems,
  available in the docket for this rulemaking (Docket Id. No. EPA-HQ-OAR-
  2023-0234).

    The majority of the proposed determinations would apply at the same
time as the proposed schedule described in section IV of this preamble.
In the case where the EPA is re-proposing from the June 2022 proposal a
determination for an existing data element where one was not previously
made, the proposed determination would be effective on January 1, 2025,
and would apply to annual reports submitted for RY2025, as well as all
prior years that the data were collected. The determination related to
the treatment of this prior year data will not change how the data was
actually treated by the Agency, it will only conform the text of the
determination to the actual confidentiality status the data has had
since it was first collected.

B. Proposed Confidentiality Determinations and Emissions Data
Designations

1. Proposed Approach
    The EPA is proposing to assess the data elements in this proposed
rule, following the same approach as described in the 2022 Proposed
Rule (87 FR 36920, June 21, 2022). In that proposal, the EPA described
a revised approach to assessing data in response to Food Marketing
Institute v. Argus Leader Media, 139 S. Ct. 2356 (2019) (hereafter
referred to as Argus Leader).\131\
---------------------------------------------------------------------------

    \131\ In the 2022 Proposed Rule (87 FR 36920, June 21, 2022),
the EPA proposed that the Argus Leader decision does not affect our
historical approach to designating data elements as ``inputs to
emission equations'' or our previous approach for designating new
and revised reporting requirements as ``emission data,'' which are
described in the July 7, 2010 proposal (75 FR 39094), 2011 Final CBI
Rule, and October 24, 2014 final rule (79 FR 63750). For reporting
elements that the EPA did not designate as ``emission data'' or
``inputs to emission equations,'' the EPA proposed to revise the
historical approach to assign data elements to data categories
established in the 2011 Final CBI Rule, and instead proposed to
assess each individual reporting element according to the Argus
Leader criteria.
---------------------------------------------------------------------------

    We propose to continue identifying new and revised reporting
elements that qualify as ``emission data'' (i.e., data necessary to
determine the identity, amount, frequency, or concentration of the
emission emitted by the reporting facilities) by evaluating the data
for assignment to one of the four data categories designated by the
2011 Final CBI Rule to meet the CAA definition of ``emission data'' in
40 CFR 2.301(a)(2)(i) \132\ (hereafter referred to as ``emission data
categories''). Refer to section II.B of the July 7, 2010, proposal for
descriptions of each of these data categories and the EPA's rationale
for designating each data category as ``emission data.''
---------------------------------------------------------------------------

    \132\ See section I.C of the July 7, 2010 proposal (75 FR 39100)
for a discussion of the definition of ``emission data.'' As
discussed therein, the relevant paragraphs (to the GHGRP) of the CAA
definition of ``emission data'' include 40 CFR 2.301(a)(2)(i)(A) and
(C), as follows: (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;'' 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).''
---------------------------------------------------------------------------

    For data elements designated as ``inputs to emission equations,''
the EPA proposes to assign data elements to one of two subcategories,
including data elements entered into IVT and those directly reported to
the EPA. See section V.C of this preamble for further descriptions of
each of these data categories.
    For new or revised data elements that the EPA does not propose to
designate as ``emission data'' or ``inputs to emission equations,'' the
EPA proposes to assess each individual reporting element according to
the Argus Leader standard, established in 2019. Accordingly, we propose
to evaluate each new or revised data element not designated as
``emission data'' or ``inputs to emission equations'' individually to
determine whether the information is customarily and actually treated
as private by the reporter and are proposing a confidentiality
determination based on that evaluation.
    Consistent with the 40 CFR part 2 procedures, this rulemaking
provides an opportunity for affected stakeholders to justify any
confidentiality claim they may have for the data they are required to
submit under parts 98 (except for emission data which are not entitled
to confidential treatment).

2. Proposed Confidentiality Determinations and ``Emission Data''
Designations

    In this section, we discuss the proposed confidentiality
determinations and ``emission data'' designations for 522 new or
substantially revised data elements. We also discuss one existing data
element (i.e., not proposed to be substantially revised) for which for
no determination has been previously established.
a. Proposed Confidentiality Determinations and ``Emission Data''
Designations for New or Substantially Revised Data Reporting Elements
    For the 522 new and substantially revised data elements, the EPA is
proposing ``emission data'' designations for 277 data elements and
confidentiality determinations for 245 data elements. The EPA is
proposing to designate 277 new or substantially revised data elements
as ``emission data'' by assigning the data elements to three emission
data categories (established in the 2011 Final CBI Rule as discussed in
section V.B.1 of this preamble), as follows:
     114 data elements that are proposed to be reported under
subpart W are proposed to be assigned to the ``Emissions'' emission
data category;

     126 data elements that are proposed to be reported under
subparts C and W are proposed to be assigned to the ``Facility and Unit
Identifier Information'' emission data category; and
     37 data elements that are proposed to be reported under
subparts C and W are proposed to be assigned to the ``Calculation
Methodology and Methodological Tier'' emission data category.
    Refer to Table 1 in the 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, available in the docket for this rulemaking
(Docket Id. No. EPA-HQ-OAR-2023-0234), for a list of these 277 data
elements proposed to be designated as ``emission data,'' the proposed
emission data category assignment for each data element, and the EPA's
rationale for each proposed ``emission data'' category assignment.
    The remaining 245 new and substantially revised data elements
proposed to be reported under subpart W are not proposed to be
designated as ``emission data,'' or ``inputs to emission equations.''
Rather, this proposal assesses each individual reporting element
according to the Argus Leader criteria as discussed in section V.B.1 of
this preamble. Refer to Table 2 in the 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, to see a list of these 245 specific
data elements, the proposed confidentiality determination for each data
element, and the EPA's rationale for each proposed confidentiality
determination. These determinations show the data elements that would
be entitled to confidential treatment if submitted to the EPA, and
those that the EPA would publish.
b. Proposed Confidentiality Determinations for Existing Part 98 Data
Elements for Which No Determination Has Been Previously Established
    We are re-proposing one confidentiality determination for a single
data element currently reported under subpart W for which no
confidentiality determination or ``emission data'' designation has been
previously finalized under part 98. In the 2022 Proposed Rule, we
reviewed previous rulemakings and found 26 data elements where a
confidentiality determination or ``emission data'' designation had not
been made under subpart W. In the 2022 Proposed Rule, we had evaluated
these data elements and proposed either confidentiality determinations
or ``emission data'' designations, using the categories established in
the 2011 Final CBI Rule. This proposal would revise 25 out of 26 of
these data elements. Therefore, these 25 revised data elements are
included in the proposed confidentiality determinations and ``emission
data'' designations discussed in section V.B.2.a of this preamble,
consistent with our approach for other data elements that we are
proposing to revise in this proposed rulemaking. That leaves one
existing data element for which no previous determination has been
finalized. We assessed the one remaining data element with no existing
confidentiality determination according to the Argus Leader criteria
and are re-proposing the confidentiality determination from the June
2022 Proposed Rule. Refer to Table 3 in the 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, available in the docket for this
rulemaking (Docket Id. No. EPA-HQ-OAR-2023-0234), for details of the
confidentiality determinations.

C. Proposed Reporting Determinations for Inputs to Emissions Equations

    In this section, we discuss data elements that the EPA proposes to
assign to the ``Inputs to Emission Equations'' data category. This data
category includes data elements that are the inputs to the emission
equations used by sources that directly emit GHGs to calculate their
annual GHG emissions.\133\ As discussed in section VI.B.1 of the 2022
Proposed Rule (87 FR 36920, June 21, 2022), the EPA determined that the
Argus Leader standard does not apply to our approach for handling data
elements assigned to the ``Inputs to Emission Equations'' data
category.
---------------------------------------------------------------------------

    \133\ For facilities that directly emit GHGs, part 98 includes
equations that facilities use to calculate emission values. The
``Inputs to Emission Equations'' data category includes the data
elements that facilities would be required to enter in the equations
to calculate the facility emissions values, e.g., monthly
consumption or production data or measured values from required
monitoring, such as carbon content. See 75 FR 39094, July 7, 2010
for a full description of the ``Inputs to Emission Equations'' data
category.
---------------------------------------------------------------------------

    The EPA organizes data assigned to the ``Inputs to Emission
Equations'' data category into two subcategories. The first subcategory
includes ``inputs to emission equations'' that must be directly
reported to the EPA. This is done in circumstances where the EPA has
determined that the data elements do not meet the criteria necessary
for them to be entered into the IVT system. These ``inputs to emission
equations,'' once received by the EPA, are not entitled to confidential
treatment. The second subcategory includes ``inputs to emission
equations'' that are entered into IVT. These ``inputs to emission
equations'' are entered into IVT to satisfy the EPA's verification
requirements. These data must be maintained as verification software
records by the submitter, but the data are not included in the annual
report that is submitted to the EPA. This is done in circumstances
where the EPA has determined that the data elements meet the criteria
necessary for them to be entered into the IVT system. Refer to the
memorandum, Proposed Reporting Determinations for Data Elements
Assigned to the Inputs to Emission Equations Data Category in Proposed
Revisions to the Greenhouse Gas Reporting Rule for Petroleum and
Natural Gas Systems, available in the docket for this rulemaking
(Docket Id. No. EPA-HQ-OAR-2023-0234), for a discussion of the criteria
established in 2011 for evaluating whether data assigned to the
``Inputs to Emission Equations'' data category should be entered into
the IVT system.
    We are proposing to assign 162 new or substantially revised data
elements in subparts C and W to the ``Inputs to Emission Equations''
data category. We evaluated each of the 162 proposed new or
substantially revised data elements assigned to the ``Inputs to
Emission Equations'' data category and determined that none of these
162 data elements meet the criteria necessary for them to be entered
into the IVT system; therefore, we propose that these 162 data elements
be directly reported to the EPA. As ``inputs to emission equations''
are emissions data, these 162 data elements would not be eligible for
confidential treatment once directly reported to the EPA, and they
would be published once received by the EPA. Refer to Table 1 in the
memorandum, Proposed Reporting Determinations for Data Elements
Assigned to the Inputs to Emission Equations Data Category in Proposed
Revisions to the Greenhouse Gas Reporting Rule for Petroleum and
Natural Gas Systems, available in the docket for this rulemaking
(Docket Id. No. EPA-HQ-OAR-2023-0234), for a list of these 162 data
elements proposed to be designated as ``inputs to emission equations''
that would be directly reported to the EPA and the EPA's

rationale for the proposed reporting determinations.

D. Request for Comments on Proposed Amendments to 40 CFR Part 2,
Category Assignments, Confidentiality Determinations, or Determinations
of Inputs To Be Reported

    We solicit comment on the proposed categories, confidentiality, and
reporting determinations in this proposed rule. By proposing
confidentiality determinations prior to data reporting through this
proposal and rulemaking process, we are providing potential reporters
an opportunity to submit comments, particularly comments addressing any
data elements not entitled to confidential treatment under this
proposal, but which reporters customarily and actually treat as
private. Likewise, we provide potential reporters an opportunity to
submit comments on whether there are disclosure concerns for data
elements proposed to be categorized as ``inputs to emission equations''
that we propose would be directly reported to the EPA via annual
reports and subsequently released by the EPA. This opportunity to
submit comments is intended to provide reporters with the opportunity
to substantiate their confidentiality claims that would ordinarily be
afforded to reporters 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 a
confidentiality determination or reporting determination is being
proposed. Upon finalizing the confidentiality determinations and
reporting determinations of the data elements identified in this
proposed rule, the EPA will release or withhold these data in
accordance with 40 CFR 2.301(d), which contains special provisions
governing the treatment of part 98 data for which confidentiality
determinations have been made through rulemaking pursuant to CAA
sections 114 and 307(d).
    If members of the public have reason to believe any data elements
in this proposed rule that are proposed to be treated as confidential
are not customarily and actually treated as private by reporters,
please provide comment explaining why the Agency should not provide an
assurance of confidential treatment for such data. Likewise, if members
of the public have reason to disagree with the EPA's proposal that
``inputs to emission equations'' qualify to be entered into IVT and
retained as verification software records instead of being directly
reported to the EPA, please provide comment explaining why the ``inputs
to emission equations'' do not qualify to be entered into IVT, should
be directly reported to the EPA, and subsequently released by the EPA.
As described in section III.D, the EPA is proposing revisions to
several existing data elements within the Onshore Petroleum and Natural
Gas Production and Onshore Petroleum and Natural Gas Gathering and
Boosting industry segments such that the data would be reported by
facilities at the site level. Under the current requirements,
facilities report much of this information aggregated across multiple
sites. Given that the proposed revisions would require that facilities
report more specific information, the EPA is requesting comment on the
confidentiality and reporting determinations for this site-level
reporting. For any revised data elements that fall into an ``emissions
data'' category, the EPA is proposing that the data would continue to
be released regardless of whether it is collected at the site level or
aggregated across sites. However, for data elements that do not fall
into an ``emissions data'' category, the EPA is seeking comment
regarding whether any of these particular data elements are customarily
and actually treated as private together with specific information
supporting this position when reported at the site level. The EPA
believes that the information in this category that would not already
be released as emission data is not information that is customarily and
actually treated as confidential by submitters, even at the site level.
The EPA is aware of outlets where much of this information is already
released publicly, such as State and local records including records
from oil and gas permitting authorities, taxing authorities, and
environmental agencies, U.S. Securities and Exchange Commission (SEC)
forms for publicly traded companies, company websites, data services
such as Enverus, S&P Global/IHS Markit, Rystad Energy and Wood
Mackenzie, and publications like Oil &Gas Journal, Petroleum Economist,
and Upstream. Upon consideration of comments, the EPA will consider
releasing this information directly as proposed, or other options that
may take into account confidentiality concerns, but still release as
much of this valuable information to the public as possible.
    When submitting comments regarding the confidentiality
determinations or reporting determinations we are proposing in this
action, please identify each individual proposed new, revised, or
existing data element you consider 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 should be considered ``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. If the data element
has been designated as an ``input to an emission equation'' (i.e., not
entitled to confidential treatment) and proposed to be directly
reported to the EPA via annual reports and subsequently released by the
EPA, please explain specifically why there are disclosure concerns.
    Please 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.
    Finally, we are not proposing new confidentiality determinations
and reporting determinations for data reporting elements proposed to be
unchanged or minimally revised because the final confidentiality
determinations and reporting determinations that the EPA made in
previous rules for these unchanged or minimally revised data elements
are unaffected by this proposed amendment and will continue to apply.
The minimally revised data elements are those where we are proposing
revisions that would not require additional or different data to be
reported. For example, we are proposing to amend 40 CFR
98.236(aa)(5)(ii) to clarify that facilities reporting to the
Underground Natural Gas Storage industry segment must report the
quantity of natural gas withdrawn from storage and sent to sale in the
calendar year. As discussed in section III.U of this preamble, we are
proposing several text edits to include ``natural'' before each
instance of ``gas'' and to use the phrase ``sent to sale'' for
consistency with CAA section 136 language. This proposed change is for
consistency in language and would not affect the data collected or the
interpretation of the terms, and therefore we are not proposing a new
or revised confidentiality determination. However, we are soliciting
comment on any cases where a minor revision would affect the previous
confidentiality determination or reporting determination. In your
comments, please identify the specific data element, including name and
citation, and explain why the minor revision would affect the previous
confidentiality determination or reporting determination.

VI. Impacts of the Proposed Amendments

    The proposed revisions would amend requirements that apply to the
petroleum and natural gas systems source category of the Greenhouse Gas
Reporting Rule consistent with CAA section 136(h) to ensure that
reporting under subpart W is based on empirical data and accurately
reflects total CH4 emissions and waste emissions from applicable
facilities, and to allow owners and operators of applicable facilities
to submit empirical emissions data that appropriately could demonstrate
the extent to which a charge is owed in future implementation of CAA
section 136. These proposed revisions include improving the existing
calculation, recordkeeping, and reporting requirements. The EPA is
proposing amendments to part 98 in order to implement improvements to
the GHGRP, including revisions to update existing emission factors and
emissions estimation methodologies, revisions to require reporting of
additional data for new emission sources and address potential gaps in
reporting, and revisions to collect data that would improve the EPA's
understanding of the sector-specific processes or other factors that
influence GHG emission rates, verification of collected data, or to
complement or inform other EPA programs. The EPA is also proposing
revisions that would improve implementation of the program, such as
those that would update applicability estimation methodologies, provide
flexibility for or simplifying calculation and monitoring
methodologies, streamline recordkeeping and reporting, and other minor
technical corrections or clarifications identified as a result of
working with the affected sources during rule implementation and
outreach. The EPA anticipates that the proposed revisions to improve
accuracy of reporting would increase costs for reporters. To the extent
consideration of costs is relevant to the EPA's proposal for meeting
its obligation under CAA section 136(h), these anticipated costs are
reasonable.
    As discussed in section V of this preamble, we are proposing to
implement these changes beginning in RY2025. Costs have been estimated
over the three years following the year of implementation. The
incremental implementation costs for each reporting year are summarized
in Table 6 of this preamble. The estimated annual average labor burden
is $41.4 million per year and the annual average labor burden per
reporter is $13,500. The incremental burden for subpart W and the
incremental costs per reporter are shown in Table 6 of this preamble.

                      Table 6--Total Incremental Labor Burden for Reporting Years 2025-2027
                                                  [$2021/year]
----------------------------------------------------------------------------------------------------------------
          Cost summary                  RY2025              RY2026              RY2027          Annual  average
----------------------------------------------------------------------------------------------------------------
Burden by Year..................  $41.4 million.....  $41.4 million.....  $41.4 million.....  $41.4 million.
Number of Reporters.............  3,077.............  3,077.............  3,077.............  3,077.
Incremental Labor Cost per        $13,500...........  $13,500...........  $13,500...........  $13,500.
 Reporter.
----------------------------------------------------------------------------------------------------------------

    There is an additional annualized incremental burden of $50.9
million for capital and operation and maintenance (O&M) costs, which
reflects changes to applicability and monitoring. Including capital and
O&M costs, the total annual average burden is $92.3 million over the
next 3 years.
    The total incremental burden and burden by reporter per subpart W
industry segment are shown in Table 7 of this preamble.

                                          Table 7--Total Incremental Burden by Industry Segment and by Reporter
                                                                    [$2021/year] \a\
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                Total annual
                        Industry segment                            Count of      Labor costs \c\    Capital and O&M   Total annual cost     cost per
                                                                  reporters \b\                        (annualized)                          reporter
--------------------------------------------------------------------------------------------------------------------------------------------------------
Onshore Petroleum and Natural Gas Production...................             777        $27,957,105        $36,301,841        $64,258,946         $82,701
Offshore Petroleum and Natural Gas Production..................             141              3,793                  0              3,793              27
Onshore Petroleum and Natural Gas Gathering and Boosting.......             361          1,490,222          4,013,157          5,503,379          15,245
Onshore Natural Gas Processing.................................             515          8,768,994          3,936,094         12,705,088          24,670
Onshore Natural Gas Transmission Compression...................           1,008          2,755,614          6,028,399          8,784,013           8,714
Natural Gas Transmission Pipeline..............................              53             87,596                187             87,783           1,656
Underground Natural Gas Storage................................              68            167,324            417,348            584,673           8,598
LNG Import and Export Equipment................................              11              4,605             18,649             23,254           2,114
LNG Storage....................................................               7             14,714             20,953             35,667           5,095
Natural Gas Distribution.......................................             164            163,069            161,370            324,439           1,978
                                                                ----------------------------------------------------------------------------------------
    Total......................................................           3,077         41,413,037         50,897,998         92,311,035          30,000
--------------------------------------------------------------------------------------------------------------------------------------------------------
\a\ Includes estimated increase in costs following implementation of revisions in RY2025.
\b\ Counts are based on GHGRP data reported in RY2020 and 567 new facilities, as detailed in the memorandum, Assessment of Burden Impacts for Proposed
  Greenhouse Gas Reporting Rule Revisions for Petroleum and Natural Gas Systems.
\c\ Initial year and subsequent year labor costs are $41.4 million per year.

    A full discussion of the cost and emission impacts may be found in
the memorandum, Assessment of Burden Impacts for Proposed Greenhouse
Gas Reporting Rule Revisions for Petroleum and Natural Gas Systems
available in the docket for this rulemaking, Docket Id. No. EPA-HQ-OAR-
2023-0234. The EPA is requesting comment on the assumptions and
methodology used in this memorandum.
    The national costs of the proposed rule reflect the fact that there
are a large number of affected entities, but per entity costs are low.
To further assess the economic impacts of the proposed rule, the EPA
conducted a screening analysis comparing the estimated total annualized
compliance costs for the petroleum and natural gas systems industry
segments with industry mean cost-to-revenue ratios based on the total
facility costs that are applicable to parent entities in each segment.
This analysis shows that the per-entity impacts within each industry
segment are low. These low mean cost-to-revenue ratios indicate that
the proposed rule is unlikely to result in significant changes in
parent entity production decisions or other choices that would result
in significant fluctuations in prices or quantities in affected
markets.

Table 8--Mean CRRs for Parent Entities by Industry Segment, All Business
                                  Sizes
------------------------------------------------------------------------
                                                    Mean CRR (standard
                Industry segment                          error)
------------------------------------------------------------------------
Onshore petroleum and natural gas production...       0.87% (0.81-0.92%)
Offshore petroleum and natural gas production..       0.06% (0.04-0.09%)
Onshore petroleum and natural gas gathering and       0.41% (0.33-0.48%)
 boosting......................................
Onshore natural gas processing.................       0.50% (0.37-0.63%)
Onshore natural gas transmission compression...       0.09% (0.06-0.12%)
Onshore natural gas transmission pipeline......       0.07% (0.05-0.10%)
Underground natural gas storage................       0.07% (0.05-0.09%)
LNG import and export equipment................       0.01% (0.00-0.01%)
LNG storage....................................       0.00% (0.00-0.00%)
Natural gas distribution.......................       0.08% (0.05-0.10%)
All segments...................................       0.60% (0.55-0.64%)
------------------------------------------------------------------------
CRR = cost-to-revenue ratio.

    The EPA also evaluated the mean costs to individual facilities and
mean costs to parents (accounting for multiple owned facilities) for
reporters (shown in Table 9 of this preamble), which are relatively
small given the high revenues of parent companies within the petroleum
and natural gas systems sector. There are currently 2,322 existing
facilities reporting to subpart W that are owned by approximately 600
parent entities. Based on a review of revenue data available for
approximately 585 parent entities, the proposed rule costs represent
less than one percent of the total annual revenue for entities that
would be reporting under subpart W.

   Table 9--Estimated Mean Costs and Revenues for Facility and Parent
                         Entities, All Segments
------------------------------------------------------------------------
                                                Estimated values (95%
                  Metric                        confidence interval)
------------------------------------------------------------------------
Mean cost to parent entity per facility     $21.7 ($21.5-$21.8).
 (thousands).
Mean number of facilities owned per parent  4.9 (4.4-5.4).
Mean cost to parent for all associated      $105.7 ($100.8-$110.7).
 facilities (thousands).
Mean parent entity revenue (billions).....  $5.18 ($4.59-$5.77).
Total revenue for all subpart W parents     $3.89 ($3.45-$4.33).
 (trillions).
Mean CRR for parent entities, using all     0.60% (0.55-0.64%).
 facility costs.
------------------------------------------------------------------------
Note: Because parent revenues are heavily skewed towards higher
  revenues, the ratio of mean cost to mean revenue (which is
  approximately 0.002%) differs substantially from the mean cost-to-
  revenue ratio (which is approximately 0.60%).

    The EPA has also considered the potential benefits of the proposed
amendments to subpart W. Because this is a proposed reporting rule, the
EPA did not quantify estimated emission reductions or monetize the
benefits from such reductions that could be associated with this
proposed action. The benefits of the proposed amendments are based on
their relevance to policy making, transparency, and market efficiency.
The proposed amendments to the reporting system for petroleum and
natural gas systems would benefit policymakers and the public by
increasing the completeness and accuracy of facility emissions data.
Public data on emissions allows for accountability of emitters to the
public. Improved facility-specific emissions data would aid local,
state, and national policymakers as they evaluate and consider future
climate change policy decisions and other policy decisions for criteria
pollutants, ambient air quality standards, and toxic air emissions. The
benefits of improved reporting of petroleum and natural gas systems GHG
emissions to government also include enhancing existing programs, such
as the Natural Gas STAR Program, that provide significant benefits,
such as identifying cost-effective technologies and practices to reduce
emissions of CH4 from operations in all of the major industry sectors--
production, gathering and processing, transmission, and distribution.
The Natural Gas STAR program leverages GHGRP reporting data to track
partner petroleum and natural gas company activities related to their
Methane Challenge commitments. The proposed changes to subpart W would
increase knowledge of the location and magnitude of significant CH4
emissions sources in the petroleum and natural gas industry, and
associated activities and technologies, which can result in
improvements in technologies and the identification of new emissions
reducing technologies.
    Benefits to industry of improved GHG emissions monitoring and
reporting under the proposed amendments include the value of having
verifiable empirical data to present to the public to demonstrate
appropriate environmental stewardship, and a better understanding of
their emission levels and sources to identify opportunities to reduce
emissions. The EPA also anticipates that improvements to monitoring and
implementation of empirical measurement methods would result in
emissions reductions. Based on activity data used to inform the U.S.
GHG Inventory, the EPA estimated approximately 403.4 billion cubic feet
of fugitive CH4 emissions (including fugitive leaks, venting, and
flaring) in 2021, representing a potential loss of over $871 million
\134\ to industry. To the extent that more frequent monitoring helps to
identify and mitigate emissions from leakage, a robust reporting
program based on empirical data can help industry and achieve and
disseminate their environmental achievements. Businesses and other
innovators can use the data to determine and track their GHG
footprints, find cost-saving efficiencies that reduce GHG emissions and
save product, and foster technologies to protect public health and the
environment. to reduce costs associated with fugitive emissions. Such
monitoring also allows for inclusion of standardized GHG data into
environmental management systems, providing the necessary information
to track actual company performance and to achieve and disseminate
their environmental achievements. Once facilities invest in the
institutional knowledge and systems to monitor and report emissions,
the cost of monitoring should fall and the accuracy of the accounting
should continue to improve. The proposed amendments would continue to
allow for facilities to benchmark themselves against similar facilities
to understand better their relative standing within their industry and
achieve and disseminate information about their environmental
performance.
---------------------------------------------------------------------------

    \134\ Based on natural gas prices from EIA (current monthly
average, April 2023). See https://www.eia.gov/dnav/ng/hist/rngwhhdm.htm.
---------------------------------------------------------------------------

    In addition, transparent public data on emissions allows for
accountability of polluters to the public who bear the cost of the
pollution. The GHGRP serves as a powerful data resource and provides a
critical tool for communities to identify nearby sources of GHGs and
provide information to state and local governments. GHGRP data are
easily accessible to the public via the EPA's online data publication
tool, also known as FLIGHT (Facility Level Information on Greenhouse
gases Tool) at: https://ghgdata.epa.gov/ghgp/main.do. FLIGHT is
designed for the general public and allows users to view and sort GHG
data from over 8,000 entities in a variety of ways including by
location, industrial sector, and type of GHG emitted, and includes
demographic data. Although the emissions reported to the EPA by
reporting facilities are global pollutants, many of these facilities
also release pollutants that have a more direct and local impact in the
surrounding communities. Citizens, community groups, and labor unions
have made use of public pollutant release data to negotiate directly
with emitters to lower emissions, avoiding the need for additional
regulatory action.
    The proposed amendments would improve the quality and transparency
of this reported data to affected communities, for example, by
providing data on other large release events. The proposed
disaggregation of reporting requirements within the Onshore Petroleum
and Natural Gas Production and Onshore Petroleum and Natural Gas
Gathering and Boosting industry segments to at least the well-pad and
gathering boosting site-level, respectively, would provide communities
with more localized information on GHG emissions from these segments.
Therefore, while the EPA has not quantified the benefits of the
proposed amendments to subpart W, the agency believes that they would
be substantial and justify the estimated costs, if finalized as
proposed. In

addition, the focus on empirical data that is the foundation of this
proposed rule was mandated by Congress in the IRA.

VII. Statutory and Executive Order Reviews

A. Executive Order 12866: Regulatory Planning and Review and Executive
Order 13563: Improving Regulation and Regulatory Review

    This action is a ``significant regulatory action'' as defined in
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-
2023-0234. The EPA prepared an analysis of the potential impacts
associated with this action. This analysis, Assessment of Burden
Impacts for Proposed Greenhouse Gas Reporting Rule Revisions for
Petroleum and Natural Gas Systems, is also available in the docket to
this rulemaking and is briefly summarized in section VI of this
preamble.

B. Paperwork Reduction Act

    The information collection activities in this proposed rule have
been submitted for approval to the OMB under the PRA. The ICR document
that the EPA prepared has been assigned OMB No. 2060-NEW (EPA ICR
number 2774.01). You can find a copy of the ICR in the docket for this
rulemaking, Docket Id. No. EPA-HQ-OAR-2023-0234, and it is briefly
summarized here.
    The EPA estimates that the proposed amendments would result in an
increase in burden. The burden associated with the proposed rule is due
to revisions that would expand reporting to include new emission
sources or that expand the industry segments covered by existing
emissions sources and that may impact the facilities that are required
to report to subpart W; revisions to emissions calculation
methodologies that would require additional monitoring; and revisions
to collect additional data to more accurately reflect and verify total
CH4 emissions in reports submitted to the GHGRP or to
provide information for future implementation of the waste emissions
charge under CAA section 136. As a result of these proposed revisions,
567 new sources are expected to become subject to subpart W. Labor and
O&M costs are included for those new sources to comply with the
reporting and recordkeeping costs detailed in EPA ICR No. 2300.18, as
well as costs to comply with these proposed revisions.
    The estimated annual average burden is 417,821 hours and $92.3
million over the 3 years covered by this information collection.
Further information on the EPA's assessment on the impact on burden can
be found in the memorandum, Assessment of Burden Impacts for Proposed
Greenhouse Gas Reporting Rule Revisions for Petroleum and Natural Gas
Systems, in the docket for this rulemaking, Docket Id. No. EPA-HQ-OAR-
2023-0234.
    Respondents/affected entities: Owners and operators of petroleum
and natural gas systems that must report their GHG emissions and other
data to the EPA to comply with 40 CFR part 98.
    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: 3,077 (affected by proposed
amendments).
    Frequency of response: Annually.
    Total estimated burden: 417,821 hours (per year). Burden is defined
at 5 CFR 1320.3(b).
    Total estimated cost: $92.3 million, includes $50.9 million
annualized capital or operation & 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 rulemaking. 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 October 2, 2023. 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 subject to the 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 production processes emit GHGs that
must be reported.
    In the implementation of the GHGRP, the EPA previously determined
thresholds that reduced the number of small businesses reporting. The
proposed revisions would not revise the threshold for existing subpart
W reporters, therefore, we do not expect a significant number of small
entities would be newly impacted under the proposed rule revisions.
    The proposed rule amendments predominantly apply to existing
reporters and are amendments that would expand reporting to include new
emission sources; add, remove, or refine emissions estimation
methodologies to improve the accuracy and transparency of reported
emission data; for the Onshore Natural Gas Production and Onshore
Natural Gas Gathering and Boosting segments, revise reporting of
emissions from a basin level to a site level; implement requirements to
collect new or revised data; clarify or update provisions that have
been misinterpreted; or streamline or simplify requirements by
increasing flexibility for reporters or removing redundant
requirements.
    The EPA conducted a small entity analysis that assessed the costs
and impacts to small entities, including: (1) Revisions to add new
emissions sources and expand the industry segments covered by existing
emissions sources, (2) changes to improve existing monitoring or
calculation methodologies, and (3) revisions to reporting and
recordkeeping requirements for data provided to the program. The Agency
anticipates that although a subset of small reporters (108-116) have a
cost-to-revenue ratio (CRR) >1%, there are only a limited number (29-
30) of very small entities (1-19 employees) that would be likely to
have significant impacts with CRR >3%, reflecting only a small
proportion of the affected small entities (2.0%-5.2%). The mean CRR for
these very small entities (1-19 employees) is estimated to be between
1.55% (1.46-1.64%) and 2.06% (1.77-2.34%) based on the incremental
costs for existing reporting entities and between 2.35% (2.16-2.55%)
and 3.12% (2.59-3.66%) based on the costs for newly reporting
entities.\135\ Details of this analysis are

presented in the memorandum, Assessment of Burden Impacts for Proposed
Greenhouse Gas Reporting Rule Revisions for Petroleum and Natural Gas
Systems, available in the docket for this rulemaking, Docket Id. No.
EPA-HQ-OAR-2023-0234. Based on the results of this analysis, we have
concluded that this proposed action is not likely to have a significant
regulatory burden for a substantial number of directly regulated small
entities and thus that this proposed action would not have a
significant economic impact on a substantial number of small entities.
The EPA continues to conduct significant outreach on the GHGRP and
maintains an ``open door'' policy for stakeholders to help inform the
EPA's understanding of key issues for the industries. We continue to be
interested in the potential impacts of the proposed rule amendments on
small entities and welcome comments on issues related to such impacts.
---------------------------------------------------------------------------

    \135\ The EPA conducted a multi-level analysis to estimate mean
CRRs for multiple scenarios. The mean CRR and associated 95-percent
confidence intervals provide an estimate of the range of cost-to-
sales ratios expected to apply to affected very small entities that
would be expected in the total population.
---------------------------------------------------------------------------

D. Unfunded Mandates Reform Act (UMRA)

    This action does not contain an unfunded mandate of $100 million or
more as described in UMRA, 2 U.S.C. 1531-1538, and does not
significantly or uniquely affect small governments. The action in part
implements mandate(s) specifically and explicitly set forth in CAA
section 136.
    This proposed rule does not apply to governmental entities unless
the government entity owns a facility in the petroleum and gas industry
that directly emits GHG above part 98 applicability threshold levels.
It does 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 an 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 subpart W revisions (see Docket Id. No. EPA-HQ-OAR-
2022-0875). The EPA received two comments from government entities
supporting the use of empirical data and improvements to the accuracy
of calculation methods under subpart W; 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 does not apply to governmental entities unless the
government entity owns a facility in the petroleum and gas industry
(e.g., an LDC) that directly emits GHG above part 98 applicability
threshold levels. Therefore, the EPA anticipates relatively few state
or local government facilities would be affected. However, consistent
with the EPA's policy to promote communications between the 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 regulation will apply
directly to petroleum and natural gas facilities that may be owned by
tribal governments that emit GHGs. However, it will generally only have
tribal implications where the tribal entity owns a facility that
directly emits GHGs above threshold levels; therefore, relatively few
tribal facilities would be affected. Of the subpart W facilities
currently reporting to the GHGRP in RY2021, we identified four
facilities currently reporting to part 98 that are owned by one tribal
parent company.
    In addition to tribes that would be directly impacted by the
proposed revisions due to owning a facility subject to the proposed
requirements, the EPA anticipates that tribes could be impacted in
cases where facilities subject to the proposed revisions are located on
Tribal land. In particular, the EPA reviewed the location of the
production wells reported by facilities under the Onshore Petroleum and
Natural Gas Production segment and found production wells reported
under subpart W on lands associated with approximately 20 tribes.
Therefore, although the EPA anticipates that only one tribe would be
subject to the rule, 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 subpart W revisions (see Docket Id. No.
EPA-HQ-OAR-2022-0875). The EPA received one comment from a tribal
entity relevant to subpart W. The commenter supported the use of
empirical data and improvements to the accuracy of calculation methods
under subpart W, including the use of advanced CH4 detection
technologies for leak surveys at well sites and compressor stations;
these comments were considered during the development of the proposed
rule. Further, consistent with the EPA Policy on Consultation and
Coordination with Indian Tribes, 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 those
regulatory actions that concern environmental health or safety risks
that the EPA has reason to believe may disproportionately affect
children, per the definition of ``covered regulatory action'' in
section 2-202 of the Executive order. This action is not subject to
Executive Order 13045 because it does not concern an environmental
health risk or safety risk.

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

    This 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. The proposed amendments would expand
reporting to include new emission sources; add, remove, or refine
emissions estimation methodologies improve the accuracy and
transparency of reported emission data; for the Onshore Natural Gas
Production and Onshore Natural Gas Gathering and Boosting segments,
revise reporting of

emissions from a basin level to a site level; implement requirements to
collect new or revised data; clarify or update provisions that have
been misinterpreted; or streamline or simplify requirements by
increasing flexibility for reporters or removing redundant
requirements. We are also proposing revisions that streamline or
simplify requirements or alleviate burden through revision,
simplification, or removal of certain calculation, monitoring,
recordkeeping, or reporting requirements. In general, these changes
would not have a significant, adverse effect on the supply,
distribution, or use of energy. In addition, the EPA is proposing
confidentiality determinations for new and revised data elements
proposed in this rulemaking and for certain existing data elements for
which a confidentiality determination has not previously been proposed.
These proposed amendments and confidentiality determinations do not
make any changes to the existing monitoring, calculation, and reporting
requirements under subpart W and are not likely to have a significant
adverse effect on the supply, distribution, or use of energy.

I. National Technology Transfer and Advancement Act and 1 CFR Part 51

    This action involves technical standards. For facilities that
conduct a performance test to calculate combustion slip, the EPA is
proposing that the performance test would be conducted in accordance
with one of the test methods in proposed 40 CFR 98.234(i), which
include EPA Methods 18 and 320 as well as an alternate method, ASTM
D6348-12. The EPA is proposing to allow the use of the alternate method
ASTM D6348-12, which is based on the use of a Fourier transform
infrared (FTIR) spectrometer for the identification and quantification
of multicomponent gaseous compounds, in lieu of EPA Method 320. The EPA
currently allows for the use of an earlier version of this method, ASTM
D6348-03, under other subparts of part 98, including subparts I
(Electronics Manufacturing), V (Nitric Acid Production), and OO
(Fluorinated Gas Production), for the quantification of other GHGs.
Therefore, the EPA is proposing to allow ASTM D6348-12 to be used in
subpart W to quantify CH4 emissions from combustion slip.
Anyone may access the standards on the ASTM website (https://www.astm.org/) for additional information. These standards are
available to everyone at a cost determined by the ASTM ($76). The ASTM
also offers memberships or subscriptions that allow unlimited access to
their methods. The cost of obtaining these methods is not a significant
financial burden, making the methods reasonably available for
reporters. The EPA will also make a copy of these documents available
in hard copy at the appropriate EPA office (see the FOR FURTHER
INFORMATION CONTACT section of this preamble for more information) for
review purposes only.

J. Executive Order 12898: Federal Actions To Address Environmental
Justice in Minority Populations and Low-Income Populations

    The EPA anticipates that the human health or environmental risk
addressed by this action will not have potential disproportionately
high and adverse human health or environmental effects on minority,
low-income or indigenous populations as it does not directly affect the
level of protection provided to human health or the environment because
it is a rule addressing information collection and reporting
procedures.
    However, the data that would be collected through this action would
provide an important data resource for communities and the public to
understand GHG emissions. Since facilities would be required to use
prescribed calculation and monitoring methods, emissions data can be
compared and analyzed, including locations of emissions sources. GHGRP
data are easily accessible to the public via the EPA's online data
publication tool, also known as FLIGHT at: https://ghgdata.epa.gov/ghgp/main.do. FLIGHT is designed for the general public and allows
users to view and sort GHG data for every reporting year starting with
2010 from over 8,000 entities in a variety of ways including by
location, industrial sector, and type of GHG emitted. This powerful
data resource provides a critical tool for communities to identify
nearby sources of GHGs and provide information to state and local
governments.
    The proposed revisions to part 98 include requirements for
reporting of GHG data from additional emission sources (other large
release events, nitrogen removal units, produced water tanks, crankcase
venting, and mud degassing), improvements to emissions calculation
methodologies, and collection of data to support verification of GHG
emissions and transparency. The proposed disaggregation of reporting
requirements within the Onshore Petroleum and Natural Gas Production
and Onshore Petroleum and Natural Gas Gathering and Boosting industry
segments to at least the well-pad and gathering boosting site-level,
respectively, and the required reporting of geographical coordinates
for other large release events would provide communities with more
localized information on GHG emissions from these segments.
    Overall, these revisions would improve the quality of the data
collected under the program and available to communities, if finalized.

K. Determination Under CAA Section 307(d)

    Pursuant to CAA section 307(d)(1)(V), the Administrator determines
that this 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 in 40 CFR Part 98

    Environmental protection, Greenhouse gases, Incorporation by
reference, Reporting and recordkeeping requirements.

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 98--MANDATORY GREENHOUSE GAS REPORTING

0
1. The authority citation for part 98 continues to read as follows:

    Authority:  42 U.S.C. 7401-7671q.

Subpart A--General Provision

0
2. Amend Sec.  98.1 by revising paragraph (c) to read as follows:

Sec.  98.1  Purpose and scope.

* * * * *
    (c) For facilities required to report under onshore petroleum and
natural gas production under subpart W of this part, the terms Owner
and Operator used in this subpart have the same definition as Onshore
petroleum and natural gas production owner or operator, as defined in
Sec.  98.238. For facilities required to report under onshore petroleum
and natural gas gathering and boosting under subpart W of this part,
the terms Owner and Operator used in this subpart have the same
definition as Gathering and boosting system owner or operator, as
defined in Sec.  98.238. For facilities required to report under
onshore natural gas transmission pipeline under subpart W of this part,
the terms Owner and

Operator used in this subpart have the same definition as Onshore
natural gas transmission pipeline owner or operator, as defined in
Sec.  98.238.
0
3. Amend Sec.  98.2 by revising paragraph (i)(3) to read as follows:

Sec.  98.2  Who must report?

* * * * *
    (i) * * *
    (3) If the operations of a facility or supplier are changed such
that all applicable processes and operations subject to paragraphs
(a)(1) through (4) of this section cease to operate, then the owner or
operator may discontinue complying with this part for the reporting
years following the year in which cessation of such operations occurs,
provided that the owner or operator submits a notification to the
Administrator that announces the cessation of reporting and certifies
to the closure of all applicable processes and operations no later than
March 31 of the year following such changes. If one or more processes
or operations subject to paragraphs (a)(1) through (4) of this section
at a facility or supplier cease to operate, but not all applicable
processes or operations cease to operate, then the owner or operator is
exempt from reporting for any such processes or operations in the
reporting years following the reporting year in which cessation of the
process or operation occurs, provided that the owner or operator
submits a notification to the Administrator that announces the
cessation of reporting for the process or operation no later than March
31 following the first reporting year in which the process or operation
has ceased for an entire reporting year. Cessation of operations in the
context of underground coal mines includes, but is not limited to,
abandoning and sealing the facility. This paragraph (i)(3) does not
apply to seasonal or other temporary cessation of operations. This
paragraph (i)(3) does not apply to the municipal solid waste landfills
source category (subpart HH of this part), or the industrial waste
landfills source category (subpart TT of this part). This paragraph
(i)(3) does not apply when there is a change in the owner or operator
for facilities in industry segments with a unique definition of
facility as defined in Sec.  98.238 of the petroleum and natural gas
systems source category (subpart W of this part), unless the changes
result in permanent cessation of all applicable processes and
operations. The owner or operator must resume reporting for any future
calendar year during which any of the GHG-emitting processes or
operations resume operation.
* * * * *
0
4. Amend Sec.  98.4 by revising the first sentence of paragraph (h) and
adding paragraph (n) to read as follows:

Sec.  98.4  Authorization and responsibilities of the designated
representative.

* * * * *
    (h) Changes in owners and operators. Except as provided in
paragraph (n) of this section, in the event an owner or operator of the
facility or supplier is not included in the list of owners and
operators in the certificate of representation under this section for
the facility or supplier, such owner or operator shall be deemed to be
subject to and bound by the certificate of representation, the
representations, actions, inactions, and submissions of the designated
representative and any alternate designated representative of the
facility or supplier, as if the owner or operator were included in such
list. * * *
* * * * *
    (n) Alternative provisions for changes in owners and operators for
industry segments with a unique definition of facility as defined in
Sec.  98.238. When there is a change to the owner or operator of a
facility required to report under the onshore petroleum and natural gas
production, natural gas distribution, onshore petroleum and natural gas
gathering and boosting, or onshore natural gas transmission pipeline
industry segments of subpart W of this part, or a change to the owner
or operator for some emission sources from the facility in one of these
industry segments, the provisions specified in paragraphs (n)(1)
through (4) of this section apply for the respective type of change in
owner or operator. The provisions specified in paragraph (n)(5) of this
section apply to the types of change in owner or operator specified in
paragraphs (n)(3) and (4) of this section.
    (1) If the entire facility is acquired by an owner or operator that
does not already have a reporting facility in the same industry segment
and basin (for onshore petroleum and natural gas production or onshore
petroleum and natural gas gathering and boosting) or state (for natural
gas distribution), then within 90 days after the change in the owner or
operator, the designated representative or any alternate designated
representative shall submit a certificate of representation that is
complete under this section. If the new owner or operator already had
emission sources specified in Sec.  98.232(c), (i), (j) or (m), as
applicable, prior to the acquisition in the same basin (for onshore
petroleum and natural gas production or onshore petroleum and natural
gas gathering and boosting) or state (for natural gas distribution) as
the acquired facility but had not previously met the applicability
requirements in Sec. Sec.  98.2(a) and 98.231, then per the applicable
definition of facility in Sec.  98.238, the previously owned applicable
emission sources must be included in the acquired facility. The new
owner or operator and the new designated representative shall be
responsible for submitting the annual report for the facility for the
entire reporting year beginning with the reporting year in which the
acquisition occurred. The new owner or operator and the new designated
representative shall also be responsible for submitting any required
annual GHG report revisions required by Sec.  98.3(h) for reporting
years prior to the reporting year in which the acquisition occurred.
    (2) If the entire facility is acquired by an owner or operator that
already has a reporting facility in the same industry segment and basin
(for onshore petroleum and natural gas production or onshore petroleum
and natural gas gathering and boosting) or state (for natural gas
distribution), the new owner or operator shall merge the acquired
facility with their existing facility for purposes of the annual GHG
report. Within 90 days after the change in the owner or operator, the
designated representative or any alternate designated representative
shall submit a certificate of representation that is complete under
this section to reflect the new owner or operator for the acquired
facility. The owner or operator shall also follow the provisions of
Sec.  98.2(i)(6) to notify EPA that the acquired facility will
discontinue reporting and shall provide the e-GGRT identification
number of the merged, or reconstituted, facility. The owner or operator
of the merged facility shall be responsible for submitting the annual
report for the merged facility for the entire reporting year beginning
with the reporting year in which the acquisition occurred. The new
owner or operator and the new designated representative shall also be
responsible for submitting any required annual GHG report revisions
required by Sec.  98.3(h) for reporting years prior to the reporting
year in which the acquisition occurred.
    (3) If only some emission sources from the facility are acquired by
one or more new owners or operators, the existing owner or operator
(i.e., the owner or operator of the portion of the facility that is not
sold) shall continue to report under subpart W of this part for the
retained emission sources unless

and until that facility meets one of the criteria in Sec.  98.2(i).
Each owner or operator that acquires emission sources from the facility
must account for those acquired emission sources according to paragraph
(n)(3)(i) or (ii) of this section, as applicable.
    (i) If the purchasing owner or operator that acquires only some of
the emission sources from the existing facility does not already have a
reporting facility in the same industry segment and basin (for onshore
petroleum and natural gas production or onshore petroleum and natural
gas gathering and boosting) or state (for natural gas distribution),
the purchasing owner or operator shall begin reporting as a new
facility. The new facility must include the acquired emission sources
specified in Sec.  98.232(c), (i), (j), or (m), as applicable, and any
emission sources the purchasing owner or operator already owned in the
same industry segment and basin (for onshore petroleum and natural gas
production or onshore petroleum and natural gas gathering and boosting)
or state (for natural gas distribution). The designated representative
for the new facility must be selected by the purchasing owner or
operator according to the schedule and procedure specified in
paragraphs (b) through (d) of this section. The purchasing owner or
operator shall be responsible for submitting the annual report for the
new facility for the entire reporting year beginning with the reporting
year in which the acquisition occurred. The purchasing owner or
operator shall continue to report under subpart W of this part for the
new facility unless and until that facility meets one of the criteria
in Sec.  98.2(i).
    (ii) If the purchasing owner or operator that acquires only some of
the emission sources from the existing facility already has a reporting
facility in the same industry segment and basin (for onshore petroleum
and natural gas production or onshore petroleum and natural gas
gathering and boosting) or state (for natural gas distribution), then
per the applicable definition of facility in Sec.  98.238, the
purchasing owner or operator must add the acquired emission sources
specified in Sec.  98.232(c), (i), (j), or (m), as applicable, to their
existing facility for purposes of reporting under subpart W. The
purchasing owner or operator shall be responsible for submitting the
annual report for the entire facility, including the acquired emission
sources, for the entire reporting year beginning with the reporting
year in which the acquisition occurred.
    (4) If all the emission sources from a reporting facility are sold
to multiple owners or operators within the same reporting year, such
that the current owner or operator of the existing facility does not
retain any of the emission sources, then the current owner or operator
of the existing facility shall notify EPA within 90 days of the last
transaction that all of the facility's emission sources were acquired
by multiple purchasers, including the identity of the purchasers. Each
owner or operator that acquires emission sources from a facility shall
account for those sources according to paragraph (n)(3)(i) or (ii) of
this section, as applicable.
    (5) Within 90 days of a transaction that results in a change to the
owner or operator of a facility as described in paragraph (n)(3) or (4)
of this section, the owners or operators involved in that transaction
shall select a historic reporting representative who will be
responsible for revisions to annual GHG reports under Sec.  98.3(h) for
reporting years prior to the reporting year in which the transaction
occurred. The historic reporting representative shall be an individual
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. The provisions of paragraphs (b), (c), (e), and (g) of
this section apply to the historic reporting representative by
substituting the term ``historic reporting representative'' for
``designated representative.'' The provisions of paragraph (i) of this
section apply to the historic reporting representative by adding the
term ``historic reporting representative'' to instances of ``the
designated representative and any alternate designated
representative.''
0
5. Amend Sec.  98.6 by revising the definitions for ``Dehydrator'',
``Dehydrator vent emissions'', ``Desiccant'', and ``Vapor recovery
system'' to read as follows:

Sec.  98.6  Definitions.

* * * * *
    Dehydrator means a device in which a liquid absorbent (including
ethylene glycol, diethylene glycol, or triethylene glycol) or desiccant
directly contacts a natural gas stream to remove water vapor.
    Dehydrator vent emissions means natural gas and CO2 released from a
natural gas dehydrator system absorbent (typically glycol) regenerator
still vent and, if present, a flash tank separator, to the atmosphere,
flare, regenerator fire-box/fire tubes, or vapor recovery system.
Emissions include stripping natural gas and motive natural gas used in
absorbent circulation pumps.
* * * * *
    Desiccant means a material used in solid-bed dehydrators to remove
water from raw natural gas by adsorption or absorption. Desiccants
include, but are not limited to, molecular sieves, activated alumina,
pelletized calcium chloride, lithium chloride and granular silica gel
material. Wet natural gas is passed through a bed of the granular or
pelletized solid adsorbent or absorbent in these dehydrators. As the
wet gas contacts the surface of the particles of desiccant material,
water is adsorbed on the surface or absorbed and dissolves the surface
of these desiccant particles. Passing through the entire desiccant bed,
almost all of the water is adsorbed onto or absorbed into the desiccant
material, leaving the dry gas to exit the contactor.
* * * * *
    Vapor recovery system means any equipment located at the source of
potential gas emissions to the atmosphere or to a flare, that is
composed of piping, connections, and, if necessary, flow-inducing
devices, and that is used for routing the gas back into the process as
a product and/or fuel. For purposes of Sec.  98.233, routing emissions
from a dehydrator regenerator still vent or flash tank separator vent
to a regenerator fire-box/fire tubes does not meet the definition of
vapor recovery system.
* * * * *
0
6. Amend Sec.  98.7 by adding paragraph (e)(53) to read as follows:

Sec.  98.7  What standardized methods are incorporated by reference
into this part?

* * * * *
    (e) * * *
    (53) ASTM D6348-12 Standard Test Method for Determination of
Gaseous Compounds by Extractive Direct Interface Fourier Transform
Infrared (FTIR) Spectroscopy, IBR approved for Sec.  98.234(j).
* * * * *
    Subpart C--General Stationary Fuel Combustion Sources
0
7. Amend Sec.  98.33 by revising parameter ``EF'' of Equation C-8 in
paragraph (c)(1) introductory text, Equation C-8a in paragraph
(c)(1)(i), Equation C-8b in paragraph (c)(1)(ii), Equation C-9a in
paragraph (c)(2), and Equation C-10 in paragraph (c)(4) introductory
text to read as follows:

Sec.  98.33  Calculating GHG emissions.

* * * * *
    (c) * * *
    (1) * * *

Where: * * *

EF = Fuel-specific default emission factor for CH4 or
N2O, from Table C-2 of this subpart (kg CH4 or
N2O per mmBtu), except for natural gas-fired
reciprocating internal combustion engines and gas turbines at
facilities subject to subpart W of this part, which must use a
CH4 emission factor determined in accordance with Sec.
98.233(z)(4).
* * * * *

    (i) * * *

Where: * * *

EF = Fuel-specific default emission factor for CH4 or
N2O, from Table C-2 of this subpart (kg CH4 or
N2O per mmBtu), except for natural gas-fired
reciprocating internal combustion engines and gas turbines at
facilities subject to subpart W of this part, which must use a
CH4 emission factor determined in accordance with Sec.
98.233(z)(4).
* * * * *

    (ii) * * *

Where: * * *

EF = Fuel-specific default emission factor for CH4 or
N2O, from Table C-2 of this subpart (kg CH4 or
N2O per mmBtu), except for natural gas-fired
reciprocating internal combustion engines and gas turbines at
facilities subject to subpart W of this part, which must use a
CH4 emission factor determined in accordance with Sec.
98.233(z)(4).
* * * * *

    (2) * * *

Where: * * *

EF = Fuel-specific default emission factor for CH4 or
N2O, from Table C-2 of this subpart (kg CH4 or
N2O per mmBtu), except for natural gas-fired
reciprocating internal combustion engines and gas turbines at
facilities subject to subpart W of this part, which must use a
CH4 emission factor determined in accordance with Sec.
98.233(z)(4).
* * * * *

    (4) * * *

Where: * * *

EF = Fuel-specific default emission factor for CH4 or
N2O, from Table C-2 of this subpart (kg CH4 or
N2O per mmBtu), except for natural gas-fired
reciprocating internal combustion engines and gas turbines at
facilities subject to subpart W of this part, which must use a
CH4 emission factor determined in accordance with Sec.
98.233(z)(4).
* * * * *
0
8. Amend Sec.  98.36 by adding paragraphs (b)(13), (c)(1)(xiii), and
(c)(3)(xiii) to read as follows:

Sec.  98.36  Data reporting requirements.

* * * * *
    (b) * * *
    (13) For natural gas-fired reciprocating internal combustion
engines or gas turbines at facilities subject to subpart W of this
part, which must use a CH4 emission factor determined in
accordance with Sec.  98.233(z)(4), you must also report:
    (i) Type of equipment: two-stroke lean-burn reciprocating internal
combustion engine, four-stroke lean-burn reciprocating internal
combustion engine, four-stroke rich-burn reciprocating internal
combustion engine, or gas turbine.
    (ii) Method by which the CH4 emission factor was
determined: performance test, manufacturer data, or default emission
factor.
    (iii) Value of the CH4 emission factor.
    (c) * * *
    (1) * * *
    (xiii) For natural gas-fired reciprocating internal combustion
engines or gas turbines at facilities subject to subpart W of this
part, which must use a CH4 emission factor determined in
accordance with Sec.  98.233(z)(4), you must report the equipment type
(i.e., two-stroke lean-burn reciprocating internal combustion engine,
four-stroke lean-burn reciprocating internal combustion engine, four-
stroke rich-burn reciprocating internal combustion engine, and gas
turbine), the method by which the CH4 emission factor was
determined (i.e., performance test, manufacturer data, or default
emission factor), and the average value of the CH4 emission
factor.
* * * * *
    (3) * * *
    (xiii) For natural gas-fired reciprocating internal combustion
engines or gas turbines at facilities subject to subpart W of this
part, which must use a CH4 emission factor determined in
accordance with Sec.  98.233(z)(4), you must report the equipment type
(i.e., two-stroke lean-burn reciprocating internal combustion engine,
four-stroke lean-burn reciprocating internal combustion engine, four-
stroke rich-burn reciprocating internal combustion engine, and gas
turbine) the method by which the CH4 emission factor was
determined (i.e., performance test, manufacturer data, or default
emission factor), and the average value of the CH4 emission
factor.
* * * * *
0
9. Amend table C-2 to subpart C of part 98 by revising the entry
``Natural Gas'' to read as follows:

 Table C-2 to Subpart C of Part 98--Default CH4 and N2O Emission Factors
                        for Various Types of Fuel
------------------------------------------------------------------------
                                      Default CH4         Default N2O
            Fuel type              emission  factor    emission  factor
                                    (kg CH4/mmBtu)      (kg N2O/mmBtu)
------------------------------------------------------------------------

                                * * * * *
Natural Gas 1...................  1.0 x 10-03.......  1.0 x 10-04.

                                * * * * *
------------------------------------------------------------------------
* * * * *
1 Reporters subject to subpart W of this part may only use the default
  CH4 emission factor for natural gas-fired combustion units that are
  not reciprocating internal combustion engines or gas turbines. For
  natural gas-fired reciprocating internal combustion engines or gas
  turbines, at facilities subject to subpart W of this part, reporters
  must use a CH4 emission factor determined in accordance with Sec.
  98.233(z)(4).

Subpart W--Petroleum and Natural Gas Systems

0
10. Amend Sec.  98.230 by revising paragraphs (a)(2), (3) and (9) to
read as follows:

Sec.  98.230  Definition of the source category.

    (a) * * *
    (2) Onshore petroleum and natural gas production. Onshore petroleum
and natural gas production means all equipment on a single well-pad or
associated with a single well-pad (including but not limited to
compressors, generators, dehydrators, storage vessels, engines,
boilers, heaters, flares, separation and processing equipment, and
portable non-self-propelled equipment, which includes well drilling and
completion equipment, workover equipment, and leased, rented or
contracted equipment) used in the production, extraction, recovery,
lifting, stabilization, separation or treating of petroleum and/or
natural gas (including condensate). This equipment also includes
associated storage or measurement vessels, all petroleum and natural
gas production equipment located on islands, artificial islands, or
structures connected by a causeway to land, an island, or an artificial
island. Onshore petroleum and natural gas production also means all
equipment on or associated with a single enhanced oil recovery (EOR)
well-pad using CO2 or natural gas injection.
    (3) Onshore natural gas processing. Onshore natural gas processing
means the forced extraction of natural gas

liquids (NGLs) from field gas, fractionation of mixed NGLs to natural
gas products, or both. Natural gas processing does not include a Joule-
Thomson valve, a dew point depression valve, or an isolated or
standalone Joule-Thomson skid. This segment also includes all residue
gas compression equipment owned or operated by the natural gas
processing plant.
* * * * *
    (9) Onshore petroleum and natural gas gathering and boosting.
Onshore petroleum and natural gas gathering and boosting means
gathering pipelines and other equipment used to collect petroleum and/
or natural gas from onshore production gas or oil wells and used to
compress, dehydrate, sweeten, or transport the petroleum and/or natural
gas to a natural gas processing facility, a natural gas transmission
pipeline or to a natural gas distribution pipeline. Gathering and
boosting equipment includes, but is not limited to gathering pipelines,
separators, compressors, acid gas removal units, dehydrators, pneumatic
devices/pumps, storage vessels, engines, boilers, heaters, and flares.
Gathering and boosting equipment does not include equipment reported
under any other industry segment defined in this section. Gathering
pipelines operating on a vacuum and gathering pipelines with a GOR less
than 300 standard cubic feet per stock tank barrel (scf/STB) are not
included in this industry segment (oil here refers to hydrocarbon
liquids of all API gravities).
* * * * *
0
11. Amend Sec.  98.232 by:
0
a. Revising paragraphs (a), (b) and (c)(2), (10), (17), and (21);
0
b. Adding paragraphs (c)(23) through (25);
0
c. Revising paragraphs (d)(5) and (7);
0
d. Adding paragraphs (d)(8) through (11);
0
e. Revising paragraphs (e)(3) and (8);
0
f. Adding paragraphs (e)(9) through (11);
0
g. Revising paragraphs (f)(6) and (8);
0
h. Adding paragraphs (f)(9) through (13);
0
i. Revising paragraphs (g)(6) and (7);
0
j. Adding paragraphs (g)(8) through (11);
0
k. Revising paragraphs (h)(7) and (8);
0
l. Adding paragraphs (h)(9) through (11) and (i)(8) through (11);
0
m. Revising paragraphs (j)(3), (6), and (10);
0
n. Adding paragraphs (j)(13) and (14);
0
o. Revising paragraph (m); and
0
p. Adding paragraph (n).
    The revisions and additions read as follows:

Sec.  98.232  GHGs to report.

    (a) You must report CO2, CH4, and
N2O emissions from each industry segment specified in
paragraphs (b) through (j) and (m) of this section, CO2,
CH4, and N2O emissions from each flare as
specified in paragraphs (b) through (j) of this section, and stationary
and portable combustion emissions as applicable as specified in
paragraph (k) of this section. You must also report the information
specified in paragraphs (l) and (n) of this section, as applicable.
    (b) For offshore petroleum and natural gas production, report
CO2, CH4, and N2O emissions from
equipment leaks, vented emission, and flare emission source types as
identified by Bureau of Ocean Energy Management (BOEM) in compliance
with 30 CFR 550.302 through 304 and CO2 and CH4
emissions from other large release events. Offshore platforms do not
need to report portable emissions.
    (c) * * *
    (2) Blowdown vent stacks.
* * * * *
    (10) Hydrocarbon liquids and produced water storage tank emissions.
* * * * *
    (17) Acid gas removal unit vents and nitrogen removal unit vents.
* * * * *
    (21) Equipment leaks listed in paragraph (c)(21)(i) or (ii) of this
section, as applicable:
    (i) Equipment leaks from components including valves, connectors,
open ended lines, pressure relief valves, pumps, flanges, and other
components (such as instruments, loading arms, stuffing boxes,
compressor seals, dump lever arms, and breather caps, but does not
include components listed in paragraph (c)(11) or (19) of this section,
and it does not include thief hatches or other openings on a storage
vessel).
    (ii) Equipment leaks from major equipment including wellheads,
separators, meters/piping, compressors, dehydrators, heaters, and
storage vessels.
* * * * *
    (23) Other large release events.
    (24) Drilling mud degassing.
    (25) Crankcase vents.
    (d) * * *
    (5) Acid gas removal unit vents and nitrogen removal unit vents.
* * * * *
    (7) Equipment leaks from valves, connectors, open ended lines,
pressure relief valves, and meters, and equipment leaks from all other
components in gas service (not including thief hatches or other
openings on storage vessels) that either are subject to equipment leak
standards for onshore natural gas processing plants in Sec.  60.5400b
of this chapter, or an applicable approved state plan or applicable
Federal plan in part 62 of this chapter or that you elect to survey
using a leak detection method described in Sec.  98.234(a).
    (8) Natural gas pneumatic device venting.
    (9) Other large release events.
    (10) Hydrocarbon liquids and produced water storage tank emissions.
    (11) Crankcase vents.
    (e) * * *
    (3) Condensate storage tanks.
* * * * *
    (8) Equipment leaks from all other components that are not listed
in paragraph (e)(1), (2), or (7) of this section and either are subject
to the well site or compressor station fugitive emissions standards in
Sec.  60.5397a of this chapter, the fugitive emissions standards for
well sites, centralized production facilities, and compressor stations
in Sec.  60.5397b of this chapter, or an applicable approved state plan
or applicable Federal plan in part 62 of this chapter, or that you
elect to survey using a leak detection method described in Sec.
98.234(a). The other components subject to this paragraph (e)(8) also
do not include thief hatches or other openings on a storage vessel.
    (9) Other large release events.
    (10) Dehydrator vents.
    (11) Crankcase vents.
    (f) * * *
    (6) Equipment leaks from all other components that are associated
with storage stations, are not listed in paragraph (f)(1), (2), or (5)
of this section, and either are subject to the well site or compressor
station fugitive emissions standards in Sec.  60.5397a of this chapter,
the fugitive emissions standards for well sites, centralized production
facilities, and compressor stations in Sec.  60.5397b of this chapter,
or an applicable approved state plan or applicable Federal plan in part
62 of this chapter or that you elect to survey using a leak detection
method described in Sec.  98.234(a). The other components subject to
this paragraph (f)(6) do not include thief hatches or other openings on
a storage vessel.
* * * * *
    (8) Equipment leaks from all other components that are associated
with storage wellheads, are not listed in paragraph (f)(1), (2), or (7)
of this section, and either are subject to the well site or compressor
station fugitive emissions standards in Sec.  60.5397a of this chapter,
the fugitive emissions standards for well sites, centralized production
facilities, and compressor stations in Sec.  60.5397b of this chapter,
or

an applicable approved state plan or applicable Federal plan in part 62
of this chapter or that you elect to survey using a leak detection
method described in Sec.  98.234(a).
    (9) Other large release events.
    (10) Dehydrator vents.
    (11) Blowdown vent stacks.
    (12) Condensate storage tanks.
    (13) Crankcase vents.
    (g) * * *
    (6) Equipment leaks from all components in gas service that are
associated with a vapor recovery compressor, are not listed in
paragraph (g)(1) or (2) of this section, and either are subject to the
well site or compressor station fugitive emissions standards in Sec.
60.5397a of this chapter, the fugitive emissions standards for well
sites, centralized production facilities, and compressor stations in
Sec.  60.5397b of this chapter, or an applicable approved state plan or
applicable Federal plan in part 62 of this chapter or that you elect to
survey using a leak detection method described in Sec.  98.234(a).
    (7) Equipment leaks from all components in gas service that are not
associated with a vapor recovery compressor, are not listed in
paragraph (g)(1) or (2) of this section, and either are subject to the
well site or compressor station fugitive emissions standards in Sec.
60.5397a of this chapter, the fugitive emissions standards for well
sites, centralized production facilities, and compressor stations in
Sec.  60.5397b of this chapter, or an applicable approved state plan or
applicable Federal plan in part 62 of this chapter or that you elect to
survey using a leak detection method described in Sec.  98.234(a).
    (8) Other large release events.
    (9) Blowdown vent stacks.
    (10) Acid gas removal unit vents and nitrogen removal unit vents.
    (11) Crankcase vents.
    (h) * * *
    (7) Equipment leaks from all components in gas service that are
associated with a vapor recovery compressor, are not listed in
paragraph (h)(1) or (2) of this section, and either are subject to the
well site or compressor station fugitive emissions standards in Sec.
60.5397a of this chapter, the fugitive emissions standards for well
sites, centralized production facilities, and compressor stations in
Sec.  60.5397b of this chapter, or an applicable approved state plan or
applicable Federal plan in part 62 of this chapter or that you elect to
survey using a leak detection method described in Sec.  98.234(a).
    (8) Equipment leaks from all components in gas service that are not
associated with a vapor recovery compressor, are not listed in
paragraph (h)(1) or (2) of this section, and either are subject to the
well site or compressor station fugitive emissions standards in Sec.
60.5397a of this chapter, the fugitive emissions standards for well
sites, centralized production facilities, and compressor stations in
Sec.  60.5397b of this chapter, or an applicable approved state plan or
applicable Federal plan in part 62 of this chapter or that you elect to
survey using a leak detection method described in Sec.  98.234(a).
    (9) Acid gas removal unit vents and nitrogen removal unit vents.
    (10) Other large release events.
    (11) Crankcase vents.
    (i) * * *
    (8) Other large release events.
    (9) Blowdown vent stacks.
    (10) Natural gas pneumatic device venting.
    (11) Crankcase vents.
    (j) * * *
    (3) Acid gas removal unit vents and nitrogen removal unit vents.
* * * * *
    (6) Hydrocarbon liquids and produced water storage tank emissions.
* * * * *
    (10) Equipment leaks listed in paragraph (j)(10)(i) or (ii) of this
section, as applicable:
    (i) Equipment leaks from components including valves, connectors,
open ended lines, pressure relief valves, pumps, flanges, and other
components (such as instruments, loading arms, stuffing boxes,
compressor seals, dump lever arms, and breather caps, but does not
include components in paragraph (j)(8) or (9) of this section, and it
does not include thief hatches or other openings on a storage vessel).
    (ii) Equipment leaks from major equipment including wellheads,
separators, meters/piping, compressors, dehydrators, heaters, and
storage vessels.
* * * * *
    (13) Other large release events.
    (14) Crankcase vents.
* * * * *
    (m) For onshore natural gas transmission pipeline, report
CO2, CH4, and N2O emissions from the
following source types:
    (1) Blowdown vent stacks.
    (2) Other large release events.
    (3) Equipment leaks at transmission company interconnect metering-
regulating stations.
    (4) Equipment leaks at farm tap and/or direct sale metering-
regulating stations.
    (5) Transmission pipeline equipment leaks.
    (n) For all facilities meeting the applicability provisions under
Sec.  98.2 and, if applicable, Sec.  98.231, report the information
required under subpart B of this part (Metered, Non-fuel, Purchased
Energy Consumption by Stationary Sources).
0
12. Amend Sec.  98.233 by:
0
a. Revising paragraphs (a), (c), (d), (e) introductory text, (e)(1)
introductory text, (e)(1)(i), (ii), (x), and (xi), and (e)(2)
introductory text;
0
b. Revising parameter ``Count'' of Equation W-5 in paragraph (e)(2);
0
c. Revising paragraph (e)(3) introductory text;
0
d. Removing paragraph (e)(4);
0
e. Redesignating paragraphs (e)(5) and (6) as (e)(4) and (5),
respectively;
0
f. Revising newly redesignated paragraphs (e)(4) and (5) and paragraphs
(f), (g) introductory text, and (g)(1) introductory text;
0
g. Removing and reserving paragraph (g)(1)(ii);
0
h. Revising parameter ``FRs,p'' and ``N'' of Equation W-12A
in paragraph (g)(1)(iii);
0
i. Revising parameters ``FRi,p'' and ``N'' of Equation W-12B
in paragraph (g)(1)(iv);
0
j. Removing paragraph (g)(4);
0
k. Revising paragraph (h) introductory text;
0
l. Removing and reserving paragraph (h)(2);
0
m. Revising paragraph (i)(2) introductory text;
0
n. Revising parameters ``Ta'' and ``Pa'' of
Equation W-14A in paragraph (i)(2)(i);
0
o. Revising parameters ``Ta,p'', ``Pa,b,p'', and
``Pa,e,p'' of Equation W-14B in paragraph (i)(2)(i);
0
p. Adding paragraph (i)(2)(iv);
0
q. Revising paragraphs (j) and (k) introductory text,
0
r. Removing paragraph (k)(5);
0
s. Revising paragraphs (l) introductory text and (l)(3);
0
t. Removing paragraph (l)(6);
0
u. Revising paragraphs (m) introductory text and (m)(3);
0
v. Removing paragraph (m)(5);
0
w. Revising paragraphs (n), (o) introductory text, (o)(1)(i)
introductory text, (o)(1)(i)(A) through (C), (o)(2) introductory text,
(o)(2)(i) introductory text, and (o)(2)(ii);
0
x. Adding paragraph (o)(2)(iii);
0
y. Removing and reserving paragraph (o)(4)(ii)(D);
0
z. Revising paragraphs (o)(4)(ii)(E) and (o)(6)(i) introductory text;
0
aa. Revising parameter ``m'' of Equation W-21 in paragraph (o)(6)(i);
0
bb. Revising paragraph (o)(6)(ii) introductory text;
0
cc. Revising parameter ``m'' of Equation W-22 in paragraph (o)(6)(ii);
0
dd. Revising paragraph (o)(6)(iii) introductory text;

0
ee. Revising parameter ``m'' of Equation W-23 in paragraph (o)(6)(iii);
0
ff. Revising parameter ``Tg'' of Equation W-24B in paragraph
(o)(8);
0
gg. Revising paragraph (o)(10);
0
hh. Removing paragraph (o)(12);
0
ii. Revising paragraphs (p) introductory text, (p)(1)(i), (p)(2)
introductory text, (p)(2)(ii) introductory text, (p)(2)(ii)(C),
(p)(2)(iii)(A), and (p)(4)(ii)(C);
0
jj. Removing and reserving paragraph (p)(4)(ii)(D);
0
kk. Revising paragraphs (p)(4)(ii)(E), (p)(6)(ii) introductory text,
and (p)(6)(iii) introductory text,
0
ll. Revising parameter ``Tg'' of Equation W-29B in paragraph
(p)(8);
0
mm. Revising paragraph (p)(10);
0
nn. Removing paragraph (p)(12);
0
oo. Revising paragraphs (q) introductory text, (q)(1), (q)(2)
introductory text, (q)(2)(i), and (q)(2)(iii) through (xi);
0
pp. Adding paragraphs (q)(3) and (4);
0
qq. Revising paragraphs (r) and (s);
0
rr. In paragraph (t)(2), revising parameter ``Za'' of
Equation W-34, and removing the undesignated paragraph following the
parameters of Equation W-34;
0
ss. Revising paragraphs (u)(2)(ii), (y), and (z);
0
tt. Adding and reserving paragraphs (aa) through (cc); and
0
uu. Adding paragraphs (dd) and (ee).
    The revisions and additions read as follows:

Sec.  98.233  Calculating GHG emissions.

* * * * *
    (a) Natural gas pneumatic device venting. For all natural gas
pneumatic devices at onshore petroleum and natural gas production
facilities, onshore petroleum and natural gas gathering and boosting
facilities, onshore natural gas processing facilities, onshore natural
gas transmission compression facilities, underground natural gas
storage facilities, and natural gas distribution facilities, use the
applicable provisions as specified in this paragraph (a) of this
section to calculate CH4 and CO2 emissions from
natural gas pneumatic device venting. If you have a flow meter on the
natural gas supply line dedicated to any one or combination of natural
gas pneumatic devices or natural gas driven pneumatic pumps vented
directly to the atmosphere for any portion of the year, you must use
the method specified in paragraph (a)(1) of this section to calculate
CH4 and CO2 emissions from those devices. For
natural gas pneumatic devices vented directly to the atmosphere for
which the natural gas supply rate is not measured, use the applicable
methods specified in paragraphs (a)(2) through (6) of this section to
calculate CH4 and CO2 emissions. For natural gas
pneumatic devices that are routed to flares, combustion, or vapor
recovery systems, use the applicable provisions specified in paragraphs
(a)(7) of this section.
    (1) Calculation Method 1. If you have or elect to install a flow
meter on the natural gas supply line dedicated to any one or
combination of natural gas pneumatic devices and natural gas driven
pneumatic pumps that are vented directly to the atmosphere, you must
use the applicable methods specified in paragraph (a)(1)(i) through
(iv) of this section to calculate CH4 and CO2
emissions from those devices.
    (i) For volumetric flow monitors:
    (A) Determine the cumulative annual volumetric flow, in standard
cubic feet, as measured by the flow monitor in the reporting year. If
all natural gas pneumatic devices supplied by the measured natural gas
supply line are routed to the atmosphere for only a portion of the year
and are routed to a flare, combustion, or vapor recovery system for the
remaining portion of the year, determine the cumulative annual
volumetric flow considering only those times when one or more of the
natural gas pneumatic devices were vented directly to the atmosphere.
If the flow meter was installed during the year, escalate the measured
volumetric flow by the ratio of the total hours for which natural gas