each component type.
    Response: In the final rule, the EPA has revised the proposed
requirement in 40 CFR 98.236(q)(1)(iii) (indicate whether any component
types are subject to the NSPS subpart OOOOa) to be clear that the EPA
expects only one yes or no response for an entire facility. While the
EPA understands that the number of leaking components and equipment
leak emissions may increase as the number of components subject to the
NSPS subpart OOOOa increases, this response will allow the EPA to
provide transparent data related to changes in emissions for facilities
with components subject to the NSPS subpart OOOOa well site or
compressor station fugitive emissions requirements over time. This data
element will also support verification that the appropriate GHGRP
monitoring method was used by the facility.

III. Confidentiality Determinations

A. Summary of Final Confidentiality Determinations for New Subpart W
Data Elements

    As noted in the proposed rule, we are applying the same approach as
previously used for making confidentiality determinations for data
elements reported under the GHGRP. In the ``Confidentiality
Determinations for Data Required Under the Mandatory Greenhouse Gas
Reporting Rule and Amendments to Special Rules Governing Certain
Information Obtained Under the Clean Air Act'' (hereafter referred to
as ``2011 Final CBI Rulemaking'') (76 FR 30782, May 26, 2011), the EPA
grouped part 98 data elements for which EPA was determining
confidentiality status through that rulemaking into 22 data categories
(11 direct emitter data categories and 11 supplier data categories)
with each of the 22 data categories containing data elements that are
similar in type or characteristics. The EPA then made categorical
confidentiality determinations for eight direct emitter data categories
and eight supplier data categories and applied the categorical
confidentiality determination to all data elements assigned to the
category. Of these data categories with categorical determinations, the
EPA determined that four direct emitter data categories are comprised
of those data elements that meet the definition of ``emission data,''
as defined at 40 CFR 2.301(a), and are, therefore, not entitled to
confidential treatment under section 114(c) of the CAA.\24\ The EPA
determined that the other four direct emitter data categories and the
eight supplier data categories do not meet the definition of ``emission
data.'' For these data categories that are determined not to be
emission data, the EPA determined categorically that data in three
direct emitter data categories and five supplier data categories are
eligible for confidential treatment as CBI, and that the data in one
direct emitter data category and three supplier data categories are
ineligible for confidential treatment as CBI. For two direct emitter
data categories, ``Unit/Process `Static' Characteristics that Are Not
Inputs to Emission Equations'' and ``Unit/Process Operating
Characteristics that Are Not Inputs to Emission Equations,'' and three
supplier data categories, ``GHGs Reported,'' ``Production/Throughput
Quantities and Composition,'' and ``Unit/Process Operating
Characteristics,'' the EPA determined in the 2011 Final CBI Rulemaking
that the data elements assigned to those categories are not emission
data, but the EPA did not make categorical CBI determinations for them.
Rather, the EPA made CBI determinations for each individual data
element included in those categories on a case-by-case basis taking
into consideration the criteria in 40 CFR 2.208. The EPA did not make a
final confidentiality determination for data elements assigned to the
inputs to emission equation data category (a direct emitter data
category) in the 2011 Final CBI Rulemaking. However, the EPA has since
proposed and finalized an approach for addressing disclosure concerns
associated with inputs to emissions equations.\25\
---------------------------------------------------------------------------

    \24\ Direct emitter data categories that meet the definition of
``emission data'' in 40 CFR 2.301(a) are ``Facility and Unit
Identifier Information,'' ``Emissions,'' ``Calculation Methodology
and Methodological Tier,'' and ``Data Elements Reported for Periods
of Missing Data that are not Inputs to Emission Equations.''
    \25\ Revisions to Reporting and Recordkeeping Requirements, and
Confidentiality Determinations Under the Greenhouse Gas Reporting
Program; Final Rule. (79 FR 63750, October 24, 2014).
---------------------------------------------------------------------------

    In the proposed rule, we assigned the nine proposed new or
substantially revised data elements to the appropriate direct emitter
data categories created in the 2011 Final CBI Rulemaking based on the
type and characteristics of each data element. For the seven data
elements the EPA assigned to a direct emitter category with a
categorical determination, the EPA proposed that the categorical
determination for the category be applied to the proposed new or
substantially revised data elements,

as shown in Table 4 of this preamble. For the two data elements
assigned to the ``Unit/Process Operating Characteristics that Are Not
Inputs to Emission Equations,'' we proposed confidentiality
determinations on a case-by-case basis taking into consideration the
criteria in 40 CFR 2.208, consistent with the approach used for data
elements previously assigned to these two data categories, as shown in
Table 5 of this preamble. Refer to the preamble to the proposed rule
(81 FR 4987; January 29, 2016) for additional information regarding the
proposed confidentiality determinations.
    With consideration of the information provided by commenters, the
EPA is finalizing the confidentiality determinations as proposed.
Specifically, the EPA is finalizing the proposed determination for each
of the nine new or substantially revised data elements to be designated
as ``emission data'' or ``not CBI.''

  Table 4--Final Data Category Assignments and Confidentiality Determinations for New Data Elements Assigned to
                                   Categories With Categorical Determinations
----------------------------------------------------------------------------------------------------------------
                                                                                Categorical
                                                                      Final category         determination (as
              Citation                       Data element               assignment         established in 2011)
                                                                                \26\
----------------------------------------------------------------------------------------------------------------
Sec.   98.236(q)(1)(i).............  The number of complete       Test and Calibration    Not Emission Data and
                                      equipment leak surveys       Methods.                Not CBI.
                                      performed during the
                                      calendar year.
Sec.   98.236(q)(1)(iii)...........  Whether any component types  Facility and Unit       Emission Data.
                                      were subject to 40 CFR       Identifier
                                      part 60, subpart OOOOa.      Information.
Sec.   98.236(q)(1)(iv)............  Whether you elected to       Facility and Unit       Emission Data.
                                      comply with Sec.             Identifier
                                      98.233(q) per Sec.           Information.
                                      98.233(q)(1)(iii).
Sec.   98.236(q)(1)(v).............  Each type of method          Test and Calibration    Not Emission Data and
                                      described in Sec.            Methods.                Not CBI.
                                      98.234(a) that was used to
                                      conduct leak surveys.
Sec.   98.236(q)(2)(i).............  For each component type      Facility and Unit       Emission Data.
                                      that is located at your      Identifier
                                      facility, component type.    Information.
Sec.   98.236(q)(2)(iv)............  For each component type      Emissions.............  Emission Data.
                                      that is located at your
                                      facility, annual CO2
                                      emissions, in metric tons
                                      CO2.
Sec.   98.236(q)(2)(v).............  For each component type      Emissions.............  Emission Data.
                                      that is located at your
                                      facility, annual CH4
                                      emissions, in metric tons
                                      CH4.
----------------------------------------------------------------------------------------------------------------

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

    \26\ The categorical confidentiality determinations for the data
categories listed in this table were finalized on May 26, 2011 (see
76 FR 30782).

 Table 5--Final Confidentiality for Data Elements Assigned to the ``Unit/Process Operating Characteristics That
                              Are Not Inputs to Emission Equations'' Data Category
----------------------------------------------------------------------------------------------------------------
                                                                        Final confidentiality determination and
                Citation                          Data element                         rationale
----------------------------------------------------------------------------------------------------------------
Sec.   98.236(q)(2)(ii).................  For each component type      Not Emission Data (Categorical
                                           that is located at your      Determination as Established in 2011).
                                           facility, total number of   Not CBI. The term ``equipment leaks''
                                           the surveyed component       refers to those emissions which could
                                           type that were identified    not reasonably pass through a stack,
                                           as leaking in the calendar   chimney, vent, or other functionally-
                                           year (``xp'' in Equation W-  equivalent opening. Leaking components
                                           30).                         at a facility may have a correlation to
                                                                        the level of maintenance at a facility.
                                                                        However, there is no direct correlation
                                                                        between the level of maintenance and
                                                                        process efficiency, i.e., a higher
                                                                        number of leaks in one facility do not
                                                                        indicate that the processes have been
                                                                        running longer or more frequently than
                                                                        those processes at another facility that
                                                                        has a lower number of leaks.
                                                                        Furthermore, Department of
                                                                        Transportation (DOT) regulations require
                                                                        natural gas distribution companies and
                                                                        transmission pipeline companies to
                                                                        conduct periodic leak detection and fix
                                                                        any leaking equipment. The number of
                                                                        leaks detected and fixed is reported to
                                                                        the DOT and is publicly available.
                                                                        Finally, 40 CFR part 60, subpart OOOOa
                                                                        requires reporting for each component
                                                                        with visible emissions at affected well
                                                                        sites and compressor station sites. The
                                                                        EPA is finalizing that this data element
                                                                        is not confidential; and that it will be
                                                                        considered ``not CBI.''
Sec.   98.236(q)(2)(iii)................  For each component type      Not Emission Data (Categorical
                                           that is located at your      Determination as Established in 2011).
                                           facility, average time the  Not CBI. This data element will provide
                                           surveyed components are      information on the amount of time
                                           assumed to be leaking and    operational components were found to be
                                           operational, in hours        leaking. This information provides
                                           (average of ``Tp,z'' from    little insight into maintenance
                                           Equation W-30).              practices at a facility because it does
                                                                        not identify the cause of the leaks or
                                                                        the nature and cost of repairs.
                                                                        Therefore, this information would not be
                                                                        likely to cause substantial competitive
                                                                        harm to reporters. For this reason, we
                                                                        are finalizing the average time
                                                                        operational components were found
                                                                        leaking be designated as ``not CBI.''
----------------------------------------------------------------------------------------------------------------

B. Summary of Comments and Responses

    This section summarizes the major comments and responses related to
the proposed categorical assignments and confidentiality
determinations. See ``Response to Public Comments on Greenhouse Gas
Reporting Rule: Leak Detection Methodology Revisions and
Confidentiality Determinations for Petroleum and Natural Gas Systems''
in Docket ID No. EPA-HQ-OAR-2015-

0764 for a complete listing of all comments and responses. See the
memorandum ``Final Data Category Assignments and Confidentiality
Determinations for Data Elements in the `Greenhouse Gas Reporting Rule:
Leak Detection Methodology Revisions and Confidentiality Determinations
for Petroleum and Natural Gas Systems; Final Rule' '' in Docket ID No.
EPA-HQ-OAR-2015-0764 for a complete listing of final data category
assignments and confidentiality determinations.
    Comment: One commenter stated that the EPA should reconsider the
proposed determination of ``not CBI'' for the number of components
identified as leaking in a calendar year and the average time the
surveyed components are assumed to be leaking. The commenter asserted
that designating this information as CBI would encourage more reporters
to voluntarily conduct leak surveys. The commenter also noted that this
information is publically available for some sources and suggested that
the rule provide an exception from classification as CBI for components
subject to State programs or NSPS that already require public
disclosure. Another commenter requested that the EPA protect the
community's right to know and not allow companies to keep the public
from finding out about leaks from hydrocarbon facilities.
    Response: While it is possible that the requirement to report the
number of leaking components and the average time those components were
leaking could discourage some reporters from conducting voluntary
equipment leak surveys, this is not a valid reason to allow reporters
to claim these data elements as confidential. As noted in section III.C
of the preamble to the proposed rule, the EPA proposed that disclosure
of these data elements is unlikely to cause substantial harm to a
business's competitive position, and the commenter did not indicate
that the EPA's determination was incorrect. Therefore, the EPA is
finalizing the confidentiality determinations for these data elements
as ``not CBI.''

IV. Impacts of the Final Amendments to Subpart W

A. Impacts of the Final Amendments

    The final amendments to subpart W revise costs associated with the
use of the monitoring methods and the calculation methodology based on
equipment leak surveys for reporters in the following industry
segments: Onshore Petroleum and Natural Gas Production, Onshore
Petroleum and Natural Gas Gathering and Boosting, Onshore Natural Gas
Transmission Compression, Underground Natural Gas Storage, LNG Storage,
and LNG Import and Export Equipment. Reporters in these industry
segments are required to use the results of fugitive emissions
component monitoring required for well sites and compressor stations
under the NSPS subpart OOOOa. Reporters in these segments with
components not subject to the NSPS subpart OOOOa well site or
compressor station fugitive emissions requirements and for which they
are currently required to use the calculation methodology based on
population counts under subpart W may voluntarily use the calculation
methodology based on equipment leak surveys for those components if the
equipment leak survey is conducted following a monitoring method listed
in subpart W.
    The EPA received comments from one commenter regarding the specific
impacts of the proposed amendments. After evaluating these comments and
reviewing other changes from proposal, the EPA revised the impacts
assessment from proposal. The EPA estimates that the costs of the final
amendments to subpart W are slightly more burdensome than we estimated
at proposal, but they do not significantly change the overall burden to
subpart W reporters. The EPA estimated that the additional costs to
subpart W reporters in the Onshore Petroleum and Natural Gas Production
and the Onshore Petroleum and Natural Gas Gathering and Boosting
industry segments to transition their existing equipment leak
recordkeeping, calculating, and reporting systems to use the
calculation methodology based on equipment leak surveys and to
determine which components are subject to the NSPS subpart OOOOa well
site or compressor station fugitive emissions requirements and which
are not, will be approximately $110,000 per year, or about $410 per
reporter. The EPA estimated that the additional costs for subpart W
reporters in the other industry segments (i.e., Onshore Natural Gas
Transmission Compression, Underground Natural Gas Storage, Liquefied
Natural Gas (LNG) Storage, and LNG Import and Export Equipment) to add
a few new emission factors to their existing systems (rather than
transitioning their recordkeeping, calculating, and reporting systems)
and to determine which components are covered by the NSPS subpart OOOOa
well site or compressor station fugitive emissions requirements and
which are not, will be approximately $20,000 per year or about $110 per
reporter. The total costs are approximately $128,400 per year for all
reporters, or about $286 per reporter. See the memorandum, ``Assessment
of Impacts of the Final Leak Detection Methodology Revisions and
Confidentiality Determinations for Petroleum and Natural Gas Systems''
in Docket ID No. EPA-HQ-OAR-2015-0764 for additional information.

B. Summary of Comments and Responses

    This section summarizes the major comments and responses related to
the impacts of the proposed amendments to subpart W of part 98. We note
that while several commenters asserted that the proposed rule would be
burdensome for many operators and suggested revisions to the rule
requirements that would reduce the burden, only one commenter provided
comments on the EPA's impacts estimate and supporting statement, and
that commenter's major comments are summarized in this section. See
``Response to Public Comments on Greenhouse Gas Reporting Rule: Leak
Detection Methodology Revisions and Confidentiality Determinations for
Petroleum and Natural Gas Systems'' in Docket ID No. EPA-HQ-OAR-2015-
0764 for a complete listing of all comments and responses.
    Comment: One commenter stated that the EPA's estimate of two hours
of labor and $198 per reporter significantly underestimates and
misrepresents the amount of time and effort that goes into implementing
a new rule. The commenter provided a cost estimate that assumes more
labor hours than in the EPA's memorandum ``Assessment of Impacts of the
Leak Detection Methodology Revisions and Confidentiality Determinations
for Petroleum and Natural Gas Systems'' (Docket Item No. EPA-HQ-OAR-
2015-0764-0025). The commenter noted that as more sites become subject
to the NSPS subpart OOOOa at a facility, the costs of managing the data
and processing it into a usable format for the GHGRP will increase each
year for that reporter. The commenter also noted that the EPA was
incorrect in assuming that there would be no costs for facilities in
the Onshore Natural Gas Processing segment.
    Response: The EPA has evaluated the comments and has made changes
to the estimate of burden in the supporting statement. The following
paragraphs address each of the points in the commenter's detailed cost
estimate included with the comment letter and explain how the points
are being addressed in the final burden and cost estimate.

    The commenter suggested adding burden of two hours in the first
year related to the initial monitoring plan development and burden of
0.5 hours in subsequent years related to yearly monitoring plan
revisions. The EPA did not include costs at proposal related to the
monitoring plan because the subpart W amendments do not require the
development of a separate monitoring plan. Instead, the subpart W
amendments cross reference the monitoring plan that is already being
developed according to the NSPS subpart OOOOa. The EPA recognizes that
reporters that are not subject to the NSPS subpart OOOOa would not
already be required to develop a monitoring plan under the NSPS subpart
OOOOa; however, reporters that elect to use one of the new leak
detection methods are also electing to incur the burden of developing a
monitoring plan. Therefore, there is no monitoring plan burden
associated with the subpart W amendments and the final burden and cost
estimate has not changed from proposal as a result of this comment.
    The commenter suggested changing the number of hours to revise the
reporting system to five hours and to allow one hour for maintenance in
each subsequent year. At proposal, the EPA estimated that revising the
reporting system to use the calculation methodology based on equipment
leak surveys would require two hours. The commenter did not provide the
basis for their estimate of five hours to update the data management
system. The overall reporting costs for compliance already include a
burden of ten hours per year and the EPA disagrees that updating the
data management system would encompass half of that allotment because
EPA anticipates that reporters would only need to add a few emission
factors for leaking components to their existing system, rather than
something more time-intensive such as creating a new data management
system. We reviewed the revisions expected to be needed in the data
management system. While we maintain that two hours are sufficient to
implement the calculation methodology based on equipment leak surveys
into a reporter's existing system, we recognize that this process will
also require quality assurance reviews and testing to ensure the data
are stored properly and the calculations are performed correctly.
Therefore, we increased the number of hours estimated to revise the
reporting system from two hours to 3.5 hours to account for these
additional quality reviews of the data management system. However, the
EPA has made no changes to burden associated with maintenance of the
revised reporting system because the EPA asserts that any reporting
system maintenance related to subpart W is already reflected in the
twenty hours per year allotted to each subpart W reporter for
recordkeeping and reporting activities.
    The commenter suggested that the EPA adjust the proposed burden and
cost estimate by adding the following activities and burden estimates:
(1) Time for staff to process the survey data resulting from the
calculation methodology based on equipment leak surveys and to enter it
into the GHGRP system at a burden of three hours per year; (2) time for
staff training at a burden of two hours for initial training and one
hour per year in subsequent years; and (3) time for staff to review the
data for quality assurance, follow missing data requirements, report
data to the EPA, and retain all records at a burden of four total hours
per year.
    At proposal, the EPA did not include burden related to these
activities because they are covered by the twenty hours per year
already accounted for in the overall subpart W reporter burden for
recordkeeping and reporting activities. Therefore, the final burden and
cost estimate has not changed from proposal as a result of these
comments.
    However, at proposal, the EPA did not account for the time
associated with determining which components in the reporting system
are covered by the NSPS subpart OOOOa well site or compressor station
fugitive emissions requirements and which are not. As a result, the EPA
has added 0.5 hours per reporter in the first year that the reporter
has an affected collection of fugitive emissions components subject to
the NSPS subpart OOOOa well site or compressor station fugitive
emissions requirements and 0.1 hours per reporter in subsequent years.
    Finally, for the reasons described in section II.B.2 of this
preamble, the final rule language specifies that the requirement to use
the NSPS subpart OOOOa results as part of the calculation methodology
based on equipment leak surveys only applies to components subject to
the NSPS subpart OOOOa well site or compressor station fugitive
emissions requirements. The subpart W equipment leak survey
requirements for facilities in the Onshore Natural Gas Processing
segment do not change as a result of these amendments. Therefore, the
EPA is not including any burden estimate for Onshore Natural Gas
Processing reporters (i.e., the revisions to the burden estimate
described in this response do not apply to the Onshore Natural Gas
Processing segment).
    Overall, the burden and cost estimate has been revised as discussed
above from 502 hours and $50,000 per year at proposal to approximately
1,295 hours and $128,400 per year for all reporters.

V. Statutory and Executive Order Reviews

    Additional information about these statutes and Executive Orders
can be found at http://www2.epa.gov/laws-and-executive orders.

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

    This action is not a significant regulatory action and was
therefore not submitted to the Office of Management and Budget (OMB)
for review.

B. Paperwork Reduction Act (PRA)

    The information collection activities in this rule have been
submitted for approval to the OMB under the PRA. The Information
Collection Request (ICR) document that the EPA prepared has been
assigned EPA ICR number 2300.19. You can find a copy of the ICR in the
docket for this rule, and it is briefly summarized here. The
information collection requirements are not enforceable until OMB
approves them.
    This action increases burden for industry segments that conduct
equipment leak surveys. These revisions are expected to increase
respondent burden for subpart W reporters that become subject to the
NSPS subpart OOOOa well site or compressor station fugitive
requirements. To accommodate the new methods and emission factors added
by these final amendments, the EPA expects that each affected subpart W
reporter will either revise their reporter-specific calculation
mechanism (i.e., calculation spreadsheet, recordkeeping database, etc.)
or add a few new emission factors to the reporter-specific calculation
mechanism, when and if the reporter becomes subject to the NSPS subpart
OOOOa well site or compressor station fugitive requirements. The
recordkeeping and reporting requirements are being finalized as
proposed. Impacts associated with the final revisions to the
recordkeeping and reporting requirements are detailed in the memorandum
``Assessment of Impacts of the Final Leak Detection Methodology
Revisions and Confidentiality Determinations for Petroleum and Natural
Gas Systems''

(see Docket ID No. EPA-HQ-OAR-2015-0764).
    Data collection provides a critical tool for communities to
identify nearby sources of GHGs and provides information to state and
local governments. The data can be used to complement atmospheric GHG
studies and inform updates to emission inventories such as the
Inventory of U.S. Greenhouse Gas Emissions and Sinks (Inventory).
Various activity data are collected that can be used to improve
understanding of the occurrence of emissions from a variety of sources.
    Data collected must be made available to the public unless the data
qualify for CBI treatment under the CAA and EPA regulations. All data
determined by the EPA to be CBI are safeguarded in accordance with
regulations in 40 CFR chapter 1, part 2, subpart B.
    Respondents/affected entities: The respondents in this information
collection include owners and operators of petroleum and natural gas
systems facilities that report their GHG emissions from equipment leaks
to the EPA to comply with subpart W.
    Respondent's obligation to respond: The respondent's obligation to
respond is mandatory under the authority provided in CAA section 114.
    Estimated number of respondents: Approximately 899 respondents per
year.
    Frequency of response: Annual.
    Total estimated burden: 1,295 hours (per year). Burden is defined
at 5 CFR 1320.3(b).
    Total estimated cost: $128,400 (per year), includes $0 annualized
capital or operation and maintenance costs.
    An agency may not conduct or sponsor, and a person is not required
to respond to, a collection of information unless it displays a
currently valid OMB control number. The OMB control numbers for the
EPA's regulations in 40 CFR are listed in 40 CFR part 9. When OMB
approves this ICR, the EPA will announce that approval in the Federal
Register and publish a technical amendment to 40 CFR part 9 to display
the OMB control number for the approved information collection
activities contained in this final rule.

C. Regulatory Flexibility Act (RFA)

    I certify that this action will not have a significant economic
impact on a substantial number of small entities under the RFA. The
small entities directly regulated by this final rule include small
businesses in the petroleum and natural gas industry. The EPA has
determined that some small businesses will be affected because their
production processes emit GHGs exceeding the reporting threshold. This
action includes amendments that may result in a small burden increase
on some subpart W reporters, but the EPA has determined that the
increased cost of less than $286 per reporter is not a significant
impact. Details of this analysis are presented in ``Assessment of
Impacts of the Final Leak Detection Methodology Revisions and
Confidentiality Determinations for Petroleum and Natural Gas Systems''
in Docket ID No. EPA-HQ-OAR-2015-0764.

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. As shown in
sections IV.A and V.B of this preamble, the annual cost of this action
is $128,400, which is well under $100 million per year.

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.

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 emit GHGs.
Although few facilities that will be subject to the rule are likely to
be owned by tribal governments, the EPA sought opportunities to provide
information to tribal governments and representatives during the
development of the proposed and final subpart W that was promulgated on
November 30, 2010 (75 FR 74458).
    The EPA consulted with tribal officials under the EPA Policy on
Consultation and Coordination with Indian Tribes early in the process
of developing this regulation to permit them to have meaningful and
timely input into its development. A summary of that consultation is
provided in section IV.F of the preamble to the re-proposal of subpart
W published on April 12, 2010 (75 FR 18608), and section IV.F of the
preamble to the subpart W 2010 final rule published on November 30,
2010 (75 FR 74458).

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 subject to Executive Order 13211, because it is
not a significant regulatory action under Executive Order 12866.

I. National Technology Transfer and Advancement Act (NTTAA)

    This rulemaking does not involve technical standards.

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

    The EPA believes that this action is not subject to Executive Order
12898 (59 FR 7629, February 16, 1994) because it does not establish an
environmental health or safety standard. Instead, this rule addresses
information collection and reporting and verification procedures.

K. Congressional Review Act (CRA)

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

List of Subjects in 40 CFR Part 98

    Environmental protection, Administrative practice and procedure,
Greenhouse gases, Reporting and recordkeeping requirements.

    Dated: November 10, 2016.
Gina McCarthy,
Administrator.

    For the reasons stated in the preamble, title 40, chapter I, of the
Code of Federal Regulations is amended 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 W--Petroleum and Natural Gas Systems

0
2. Section 98.232 is amended by:
0
a. Revising paragraph (c)(21);
0
b. Adding paragraph (e)(8);
0
c. Revising paragraph (f)(5);
0
d. Adding paragraphs (f)(6) through (8);
0
e. Revising paragraphs (g)(3) and (4);
0
f. Adding paragraphs (g)(5) through (7);
0
g. Revising paragraphs (h)(4) and (5);
0
h. Adding paragraphs (h)(6) through (8); and
0
i. Revising paragraph (j)(10).
    The revisions and additions read as follows:

Sec.  98.232  GHGs to report.

* * * * *
    (c) * * *
    (21) Equipment leaks from 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).
* * * * *
    (e) * * *
    (8) Equipment leaks from all other components that are not listed
in paragraph (e)(1), (2), or (7) of this section and are either subject
to the well site or compressor station fugitive emissions standards in
Sec.  60.5397a of this chapter or you elect to survey using a leak
detection method described in Sec.  98.234(a)(6) or (7). The other
components subject to this paragraph (e)(8) also do not include thief
hatches or other openings on a storage vessel. If these other
components are not subject to the well site or compressor station
fugitive emissions standards in Sec.  60.5397a of this chapter, you may
also elect to report emissions from these other components if you elect
to survey them using a leak detection method described in Sec.
98.234(a)(1) through (5).
    (f) * * *
    (5) Equipment leaks from valves, connectors, open ended lines,
pressure relief valves, and meters associated with storage stations.
    (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 are either subject to the well site or compressor
station fugitive emissions standards in Sec.  60.5397a of this chapter
or you elect to survey using a leak detection method described in Sec.
98.234(a)(6) or (7). If these other components are not subject to the
well site or compressor station fugitive emissions standards in Sec.
60.5397a of this chapter, you may also elect to report emissions from
these other components if you elect to survey them using a leak
detection method described in Sec.  98.234(a)(1) through (5).
    (7) Equipment leaks from valves, connectors, open-ended lines, and
pressure relief valves associated with storage wellheads.
    (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 are either subject to the well site or compressor
station fugitive emissions standards in Sec.  60.5397a, of this chapter
or you elect to survey using a leak detection method described in Sec.
98.234(a)(6) or (7). If these other components are not subject to the
well site or compressor station fugitive emissions standards in Sec.
60.5397a of this chapter, you may also elect to report emissions from
these other components if you elect to survey them using a leak
detection method described in Sec.  98.234(a)(1) through (5).
    (g) * * *
    (3) Flare stack emissions.
    (4) Equipment leaks from valves, pump seals, connectors, and other
equipment leak sources in LNG service.
    (5) Equipment leaks from vapor recovery compressors, if you do not
survey components associated with vapor recovery compressors in
accordance with paragraph (g)(6) of this section.
    (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 that are either subject to
the well site or compressor station fugitive emissions standards in
Sec.  60.5397a of this chapter or 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 are either subject to the
well site or compressor station fugitive emissions standards in Sec.
60.5397a of this chapter or you elect to survey using a leak detection
method described in Sec.  98.234(a)(6) or (7). If these components are
not subject to the well site or compressor station fugitive emissions
standards in Sec.  60.5397a of this chapter, you may also elect to
report emissions from these components if you elect to survey them
using a leak detection method described in Sec.  98.234(a)(1) through
(5).
    (h) * * *
    (4) Flare stack emissions.
    (5) Equipment leaks from valves, pump seals, connectors, and other
equipment leak sources in LNG service.
    (6) Equipment leaks from vapor recovery compressors, if you do not
survey components associated with vapor recovery compressors in
accordance with paragraph (h)(7) of this section.
    (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 that are either subject to
the well site or compressor station fugitive emissions standards in
Sec.  60.5397a of this chapter or 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 that are either subject to
the well site or compressor station fugitive emissions standards in
Sec.  60.5397a of this chapter or you elect to survey using a leak
detection method described in Sec.  98.234(a)(6) or (7). If these
components are not subject to the well site or compressor station
fugitive emissions standards in Sec.  60.5397a of this chapter, you may
also elect to report emissions from these components if you elect to
survey them using a leak detection method described in Sec.
98.234(a)(1) through (5).
* * * * *
    (j) * * *
    (10) Equipment leaks from 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).
* * * * *

0
3. Section 98.233 is amended by:
0
a. Revising the parameter EFt of Equation W-1 in paragraph
(a) introductory text, and paragraph (q);

0
b. Removing the first two sentences of paragraph (r) introductory text
and adding four sentences in their place; and
0
c. Revising the parameters Counte and EFs,e of
Equation W-32A in paragraph (r) introductory text, and paragraphs
(r)(3) through (5).
    The revisions read as follows:

Sec.  98.233  Calculating GHG emissions.

* * * * *
    (a) * * *
* * * * *

EFt = Population emission factors for natural gas
pneumatic device vents (in standard cubic feet per hour per device)
of each type ``t'' listed in Tables W-1A, W-3B, and W-4B to this
subpart for onshore petroleum and natural gas production, onshore
natural gas transmission compression, and underground natural gas
storage facilities, respectively. Onshore petroleum and natural gas
gathering and boosting facilities must use the population emission
factors listed in Table W-1A to this subpart.

* * * * *
    (q) Equipment leak surveys. For the components identified in
paragraphs (q)(1)(i) through (iii) of this section, you must conduct
equipment leak surveys using the leak detection methods specified in
paragraphs (q)(1)(i) through (iii) of this section. For the components
identified in paragraph (q)(1)(iv) of this section, you may elect to
conduct equipment leak surveys, and if you elect to conduct surveys,
you must use a leak detection method specified in paragraph (q)(1)(iv)
of this section. This paragraph (q) applies to components in streams
with gas content greater than 10 percent CH4 plus
CO2 by weight. Components in streams with gas content less
than or equal to 10 percent CH4 plus CO2 by
weight are exempt from the requirements of this paragraph (q) and do
not need to be reported. Tubing systems equal to or less than one half
inch diameter are exempt from the requirements of this paragraph (q)
and do not need to be reported.
    (1) Survey requirements. (i) For the components listed in Sec.
98.232(e)(7), (f)(5), (g)(4), and (h)(5), that are not subject to the
well site or compressor station fugitive emissions standards in Sec.
60.5397a of this chapter, you must conduct surveys using any of the
leak detection methods listed in Sec.  98.234(a) and calculate
equipment leak emissions using the procedures specified in paragraph
(q)(2) of this section.
    (ii) For the components listed in Sec.  98.232(d)(7) and (i)(1),
you must conduct surveys using any of the leak detection methods listed
in Sec.  98.234(a)(1) through (5) and calculate equipment leak
emissions using the procedures specified in paragraph (q)(2) of this
section.
    (iii) For the components listed in Sec.  98.232(c)(21), (e)(7),
(e)(8), (f)(5), (f)(6), (f)(7), (f)(8), (g)(4), (g)(6), (g)(7), (h)(5),
(h)(7), (h)(8), and (j)(10) that are subject to the well site or
compressor station fugitive emissions standards in Sec.  60.5397a of
this chapter, you must conduct surveys using any of the leak detection
methods in Sec.  98.234(a)(6) or (7) and calculate equipment leak
emissions using the procedures specified in paragraph (q)(2) of this
section.
    (iv) For the components listed in Sec.  98.232(c)(21), (e)(8),
(f)(6), (f)(7), (f)(8), (g)(6), (g)(7), (h)(7), (h)(8), or (j)(10),
that are not subject to fugitive emissions standards in Sec.  60.5397a
of this chapter, you may elect to conduct surveys according to this
paragraph (q), and, if you elect to do so, then you must use one of the
leak detection methods in Sec.  98.234(a).
    (A) If you elect to use a leak detection method in Sec.
98.234(a)(1) through (5) for the surveyed component types in Sec.
98.232(c)(21), (f)(7), (g)(6), (h)(7), or (j)(10) in lieu of the
population count methodology specified in paragraph (r) of this
section, then you must calculate emissions for the surveyed component
types in Sec.  98.232(c)(21), (f)(7), (g)(6), (h)(7), or (j)(10) using
the procedures in paragraph (q)(2) of this section.
    (B) If you elect to use a leak detection method in Sec.
98.234(a)(1) through (5) for the surveyed component types in Sec.
98.232(e)(8), (f)(6), (f)(8), (g)(7), and (h)(8), then you must use the
procedures in paragraph (q)(2) of this section to calculate those
emissions.
    (C) If you elect to use a leak detection method in Sec.
98.234(a)(6) or (7) for any elective survey under this subparagraph
(q)(1)(iv), then you must survey the component types in Sec.
98.232(c)(21), (e)(8), (f)(6), (f)(7), (f)(8), (g)(6), (g)(7), (h)(7),
(h)(8), and (j)(10) that are not subject to fugitive emissions
standards in Sec.  60.5397a of this chapter, and you must calculate
emissions from the surveyed component types in Sec.  98.232(c)(21),
(e)(8), (f)(6), (f)(7), (f)(8), (g)(6), (g)(7), (h)(7), (h)(8), and
(j)(10) using the emission calculation requirements in paragraph (q)(2)
of this section.
    (2) Emission calculation methodology. For industry segments listed
in Sec.  98.230(a)(2) through (9), if equipment leaks are detected
during surveys required or elected for components listed in paragraphs
(q)(1)(i) through (iv) of this section, then you must calculate
equipment leak emissions per component type per reporting facility
using Equation W-30 of this section and the requirements specified in
paragraphs (q)(2)(i) through (xi) of this section. For the industry
segment listed in Sec.  98.230(a)(8), the results from Equation W-30
are used to calculate population emission factors on a meter/regulator
run basis using Equation W-31 of this section. If you chose to conduct
equipment leak surveys at all above grade transmission-distribution
transfer stations over multiple years, ``n,'' according to paragraph
(q)(2)(x)(A) of this section, then you must calculate the emissions
from all above grade transmission-distribution transfer stations as
specified in paragraph (q)(2)(xi) of this section.
[GRAPHIC] [TIFF OMITTED] TR30NO16.000

Where:

Es,p,i = Annual total volumetric emissions of GHGi from
specific component type ``p'' (in accordance with paragraphs
(q)(1)(i) through (iv) of this section) in standard (``s'') cubic
feet, as specified in paragraphs (q)(2)(ii) through (x) of this
section.
xp = Total number of specific component type ``p''
detected as leaking in any leak survey during the year. A component
found leaking in two or more surveys during the year is counted as
one leaking component.
EFs,p = Leaker emission factor for specific component
types listed in Tables W-1E, W-2, W-3A, W-4A, W-5A, W-6A, and W-7 to
this subpart.
GHGi = For onshore petroleum and natural gas production
facilities and onshore petroleum and natural gas gathering and
boosting facilities, concentration of GHGi,
CH4, or CO2, in produced natural gas as
defined in paragraph (u)(2) of this section; for onshore natural gas
processing facilities, concentration of GHGi,
CH4 or CO2, in the total hydrocarbon of the
feed natural gas; for onshore natural gas transmission compression
and underground natural

gas storage, GHGi equals 0.975 for CH4 and 1.1
x 10-2 for CO2; for LNG storage and LNG import
and export equipment, GHGi equals 1 for CH4
and 0 for CO2; and for natural gas distribution,
GHGi equals 1 for CH4 and 1.1 x
10-2 CO2.
Tp,z = The total time the surveyed component ``z,''
component type ``p,'' was assumed to be leaking and operational, in
hours. If one leak detection survey is conducted in the calendar
year, assume the component was leaking for the entire calendar year.
If multiple leak detection surveys are conducted in the calendar
year, assume a component found leaking in the first survey was
leaking since the beginning of the year until the date of the
survey; assume a component found leaking in the last survey of the
year was leaking from the preceding survey through the end of the
year; assume a component found leaking in a survey between the first
and last surveys of the year was leaking since the preceding survey
until the date of the survey; and sum times for all leaking periods.
For each leaking component, account for time the component was not
operational (i.e., not operating under pressure) using an
engineering estimate based on best available data.

    (i) You must conduct at least one leak detection survey in a
calendar year. The leak detection surveys selected must be conducted
during the calendar year. If you conduct multiple complete leak
detection surveys in a calendar year, you must use the results from
each complete leak detection survey when calculating emissions using
Equation W-30. For components subject to the well site and compressor
station fugitive emissions standards in Sec.  60.5397a of this chapter,
each survey conducted in accordance with Sec.  60.5397a of this chapter
will be considered a complete leak detection survey for purposes of
this section.
    (ii) Calculate both CO2 and CH4 mass
emissions using calculations in paragraph (v) of this section.
    (iii) Onshore petroleum and natural gas production facilities must
use the appropriate default whole gas leaker emission factors for
components in gas service, light crude service, and heavy crude service
listed in Table W-1E to this subpart.
    (iv) Onshore petroleum and natural gas gathering and boosting
facilities must use the appropriate default whole gas leaker factors
for components in gas service listed in Table W-1E to this subpart.
    (v) Onshore natural gas processing facilities must use the
appropriate default total hydrocarbon leaker emission factors for
compressor components in gas service and non-compressor components in
gas service listed in Table W-2 to this subpart.
    (vi) Onshore natural gas transmission compression facilities must
use the appropriate default total hydrocarbon leaker emission factors
for compressor components in gas service and non-compressor components
in gas service listed in Table W-3A to this subpart.
    (vii) Underground natural gas storage facilities must use the
appropriate default total hydrocarbon leaker emission factors for
storage stations or storage wellheads in gas service listed in Table W-
4A to this subpart.
    (viii) LNG storage facilities must use the appropriate default
methane leaker emission factors for LNG storage components in LNG
service or gas service listed in Table W-5A to this subpart.
    (ix) LNG import and export facilities must use the appropriate
default methane leaker emission factors for LNG terminals components in
LNG service or gas service listed in Table W-6A to this subpart.
    (x) Natural gas distribution facilities must use Equation W-30 of
this section and the default methane leaker emission factors for
transmission-distribution transfer station components in gas service
listed in Table W-7 to this subpart to calculate component emissions
from annual equipment leak surveys conducted at above grade
transmission-distribution transfer stations. Natural gas distribution
facilities are required to perform equipment leak surveys only at above
grade stations that qualify as transmission-distribution transfer
stations. Below grade transmission-distribution transfer stations and
all metering-regulating stations that do not meet the definition of
transmission-distribution transfer stations are not required to perform
equipment leak surveys under this section.
    (A) Natural gas distribution facilities may choose to conduct
equipment leak surveys at all above grade transmission-distribution
transfer stations over multiple years ``n,'' not exceeding a five year
period to cover all above grade transmission-distribution transfer
stations. If the facility chooses to use the multiple year option, then
the number of transmission-distribution transfer stations that are
monitored in each year should be approximately equal across all years
in the cycle.
    (B) Use Equation W-31 of this section to determine the meter/
regulator run population emission factors for each GHGi. As
additional survey data become available, you must recalculate the
meter/regulator run population emission factors for each
GHGi annually according to paragraph (q)(2)(x)(C) of this
section.
[GRAPHIC] [TIFF OMITTED] TR30NO16.001

Where:

EFs,MR,i = Meter/regulator run population emission factor
for GHGi based on all surveyed above grade transmission-
distribution transfer stations over ``n'' years, in standard cubic
feet of GHGi per operational hour of all meter/regulator
runs.
Es,p,i,y = Annual total volumetric emissions at standard
conditions of GHGi from component type ``p'' during year
``y'' in standard (``s'') cubic feet, as calculated using Equation
W-30 of this section.
p = Seven component types listed in Table W-7 to this subpart for
transmission-distribution transfer stations.
Tw,y = The total time the surveyed meter/regulator run
``w'' was operational, in hours during survey year ``y'' using an
engineering estimate based on best available data.
CountMR,y = Count of meter/regulator runs surveyed at
above grade transmission-distribution transfer stations in year
``y''.
y = Year of data included in emission factor ``EFs,MR,i''
according to paragraph (q)(2)(x)(C) of this section.
n = Number of years of data, according to paragraph (q)(2)(x)(A) of
this section, whose results are used to calculate emission factor
``EFs,MR,i'' according to paragraph (q)(2)(x)(C) of this
section.

    (C) The emission factor ``EFs,MR,i,'' based on annual
equipment leak surveys at above grade transmission-distribution
transfer stations, must be calculated

annually. If you chose to conduct equipment leak surveys at all above
grade transmission-distribution transfer stations over multiple years,
``n,'' according to paragraph (q)(2)(x)(A) of this section and you have
submitted a smaller number of annual reports than the duration of the
selected cycle period of 5 years or less, then all available data from
the current year and previous years must be used in the calculation of
the emission factor ``EFs,MR,i'' from Equation W-31 of this
section. After the first survey cycle of ``n'' years is completed and
beginning in calendar year (n+1), the survey will continue on a rolling
basis by including the survey results from the current calendar year
``y'' and survey results from all previous (n-1) calendar years, such
that each annual calculation of the emission factor
``EFs,MR,i'' from Equation W-31 is based on survey results
from ``n'' years. Upon completion of a cycle, you may elect to change
the number of years in the next cycle period (to be 5 years or less).
If the number of years in the new cycle is greater than the number of
years in the previous cycle, calculate ``EFs,MR,i'' from
Equation W-31 in each year of the new cycle using the survey results
from the current calendar year and the survey results from the
preceding number years that is equal to the number of years in the
previous cycle period. If the number of years, ``nnew,'' in
the new cycle is smaller than the number of years in the previous
cycle, ``n,'' calculate ``EFs,MR,i'' from Equation W-31 in
each year of the new cycle using the survey results from the current
calendar year and survey results from all previous (nnew-1)
calendar years.
    (xi) If you chose to conduct equipment leak surveys at all above
grade transmission-distribution transfer stations over multiple years,
``n,'' according to paragraph (q)(2)(x)(A) of this section, you must
use the meter/regulator run population emission factors calculated
using Equation W-31 of this section and the total count of all meter/
regulator runs at above grade transmission-distribution transfer
stations to calculate emissions from all above grade transmission-
distribution transfer stations using Equation W-32B in paragraph (r) of
this section.
    (r) * * * This paragraph (r) applies to emissions sources listed in
Sec.  98.232(c)(21), (f)(7), (g)(5), (h)(6), and (j)(10) if you are not
required to comply with paragraph (q) of this section and if you do not
elect to comply with paragraph (q) of this section for these components
in lieu of this paragraph (r). This paragraph (r) also applies to
emission sources listed in Sec.  98.232(i)(2), (i)(3), (i)(4), (i)(5),
(i)(6), and (j)(11). To be subject to the requirements of this
paragraph (r), the listed emissions sources also must contact streams
with gas content greater than 10 percent CH plus
CO2 by weight. Emissions sources that contact streams with
gas content less than or equal to 10 percent CH4 plus
CO2 by weight are exempt from the requirements of this
paragraph (r) and do not need to be reported. * * *
* * * * *

Counte = Total number of the emission source type at the
facility. For onshore petroleum and natural gas production
facilities and onshore petroleum and natural gas gathering and
boosting facilities, average component counts are provided by major
equipment piece in Tables W-1B and Table W-1C to this subpart. Use
average component counts as appropriate for operations in Eastern
and Western U.S., according to Table W-1D to this subpart. Onshore
petroleum and natural gas gathering and boosting facilities must
also count the miles of gathering pipelines by material type
(protected steel, unprotected steel, plastic, or cast iron).
Underground natural gas storage facilities must count each component
listed in Table W-4B to this subpart. LNG storage facilities must
count the number of vapor recovery compressors. LNG import and
export facilities must count the number of vapor recovery
compressors. Natural gas distribution facilities must count: (1) The
number of distribution services by material type; (2) miles of
distribution mains by material type; and (3) number of below grade
metering-regulating stations, by pressure type; as listed in Table
W-7 to this subpart.
* * * * *
EFs,e = Population emission factor for the specific
emission source type, as listed in Tables W-1A, W-4B, W-5B, W-6B,
and W-7 to this subpart. Use appropriate population emission factor
for operations in Eastern and Western U.S., according to Table W-1D
to this subpart.
* * * * *

    (3) Underground natural gas storage facilities must use the
appropriate default total hydrocarbon population emission factors for
storage wellheads in gas service listed in Table W-4B to this subpart.
    (4) LNG storage facilities must use the appropriate default methane
population emission factor for LNG storage compressors in gas service
listed in Table W-5B to this subpart.
    (5) LNG import and export facilities must use the appropriate
default methane population emission factor for LNG terminal compressors
in gas service listed in Table W-6B to this subpart.
* * * * *

0
4. Section 98.234 is amended by:
0
a. Revising paragraph (a) introductory text, the paragraph (a)(1)
heading, and the fourth sentence in paragraph (a)(2); and
0
b. Adding paragraphs (a)(6) and (7).
    The revisions and additions read as follows:
* * * * *

Sec.  98.234  Monitoring and QA/QC requirements.

    (a) You must use any of the methods described in paragraphs (a)(1)
through (5) of this section to conduct leak detection(s) of through-
valve leakage from all source types listed in Sec.  98.233(k), (o), and
(p) that occur during a calendar year. You must use any of the methods
described in paragraphs (a)(1) through (7) of this section to conduct
leak detection(s) of equipment leaks from components as specified in
Sec.  98.233(q)(1)(i) that occur during a calendar year. You must use
any of the methods described in paragraphs (a)(1) through (5) of this
section to conduct leak detection(s) of equipment leaks from components
as specified in Sec.  98.233(q)(1)(ii) that occur during a calendar
year. You must use one of the methods described in paragraph (a)(6) or
(7) of this section to conduct leak detection(s) of equipment leaks
from components as specified in Sec.  98.233(q)(1)(iii). If electing to
comply with Sec.  98.233(q) as specified in Sec.  98.233(q)(1)(iv), you
must use any of the methods described in paragraphs (a)(1) through (7)
of this section to conduct leak detection(s) of equipment leaks from
component types as specified in Sec.  98.233(q)(1)(iv) that occur
during a calendar year.
    (1) Optical gas imaging instrument as specified in Sec.  60.18 of
this chapter. * * *
* * * * *
    (2) * * * If the equipment leak detection methods in this paragraph
cannot be used, you must use alternative leak detection devices as
described in paragraph (a)(1) of this section to monitor inaccessible
equipment leaks or vented emissions.
* * * * *
    (6) Optical gas imaging instrument as specified in Sec.  60.5397a
of this chapter. Use an optical gas imaging instrument for equipment
leak detection in accordance with Sec.  60.5397a(b), (c)(3), (c)(7),
and (e) of this chapter and paragraphs (a)(6)(i) through (iii) of this
section. Unless using methods in paragraph (a)(7) of this section, an
optical gas imaging instrument must be used for all source types that
are inaccessible and cannot be monitored without elevating the
monitoring

personnel more than 2 meters above a support surface.
    (i) For the purposes of this subpart, any visible emissions from a
component listed in Sec.  98.232 observed by the optical gas imaging
instrument is a leak.
    (ii) For the purposes of this subpart, the term ``fugitive
emissions component'' in Sec.  60.5397a of this chapter means
``component.''
    (iii) For the purpose of complying with Sec.  98.233(q)(1)(iv), the
phrase ``the collection of fugitive emissions components at well sites
and compressor stations'' in Sec.  60.5397a(b) of this chapter means
``the collection of components for which you elect to comply with Sec.
98.233(q)(1)(iv).''
    (7) Method 21 as specified in Sec.  60.5397a of this chapter. Use
the equipment leak detection methods in appendix A-7 to part 60 of this
chapter, Method 21, in accordance with Sec.  60.5397a(b), (c)(8), and
(e) of this chapter and paragraphs (a)(7)(i) through (iii) of this
section. Inaccessible emissions sources, as defined in part 60 of this
chapter, are not exempt from this subpart. If the equipment leak
detection methods in this paragraph cannot be used, you must use
alternative leak detection devices as described in paragraph (a)(6) of
this section to monitor inaccessible equipment leaks.
    (i) For the purposes of this subpart, any instrument reading from a
component listed in Sec.  98.232 of this chapter of 500 ppm or greater
using Method 21 is a leak.
    (ii) For the purposes of this subpart, the term ``fugitive
emissions component'' in Sec.  60.5397a of this chapter means
``component.''
    (iii) For the purpose of complying with Sec.  98.233(q)(1)(iv), the
phrase ``the collection of fugitive emissions components at well sites
and compressor stations'' in Sec.  60.5397a(b) of this chapter means
``the collection of components for which you elect to comply with Sec.
98.233(q)(1)(iv).''
* * * * *

0
5. Section 98.236 is amended by:
0
a. Redesignating paragraphs (a)(1)(xiv) through (xvii) as paragraphs
(a)(1)(xv) through (xviii), respectively;
0
b. Adding new paragraph (a)(1)(xiv);
0
c. Redesignating paragraphs (a)(9)(x) and (xi) as paragraphs (a)(9)(xi)
and (xii), respectively;
0
d. Adding new paragraph (a)(9)(x);
0
e. Revising paragraph (q) introductory text, paragraph (q)(1),
paragraph (q)(2) introductory text, paragraph (r)(3)(ii) introductory
text, and the second sentence of paragraph (z) introductory text.
    The revisions and additions read as follows:

Sec.  98.236   Data reporting requirements.

* * * * *
    (a) * * *
    (1) * * *
    (xiv) Equipment leak surveys. Report the information specified in
paragraph (q) of this section.
* * * * *
    (9) * * *
    (x) Equipment leak surveys. Report the information specified in
paragraph (q) of this section.
* * * * *
    (q) Equipment leak surveys. For any components subject to or
complying with the requirements of Sec.  98.233(q), you must report the
information specified in paragraphs (q)(1) and (2) of this section.
Natural gas distribution facilities with emission sources listed in
Sec.  98.232(i)(1) must also report the information specified in
paragraph (q)(3) of this section.
    (1) You must report the information specified in paragraphs
(q)(1)(i) through (v) of this section.
    (i) Except as specified in paragraph (q)(1)(ii) of this section,
the number of complete equipment leak surveys performed during the
calendar year.
    (ii) Natural gas distribution facilities performing equipment leak
surveys across a multiple year leak survey cycle must report the number
of years in the leak survey cycle.
    (iii) Except for onshore natural gas processing facilities and
natural gas distribution facilities, indicate whether any equipment
components at your facility are subject to the well site or compressor
station fugitive emissions standards in Sec.  60.5397a of this chapter.
Report the indication per facility, not per component type.
    (iv) For facilities in onshore petroleum and natural gas
production, onshore petroleum and natural gas gathering and boosting,
onshore natural gas transmission compression, underground natural gas
storage, LNG storage, and LNG import and export equipment, indicate
whether you elected to comply with Sec.  98.233(q) according to Sec.
98.233(q)(1)(iv) for any equipment components at your facility.
    (v) Report each type of method described in Sec.  98.234(a) that
was used to conduct leak surveys.
    (2) You must indicate whether your facility contains any of the
component types subject to or complying with Sec.  98.233(q) that are
listed in Sec.  98.232(c)(21), (d)(7), (e)(7), (e)(8), (f)(5), (f)(6),
(f)(7), (f)(8), (g)(4), (g)(6), (g)(7), (h)(5), (h)(7), (h)(8), (i)(1),
or (j)(10) for your facility's industry segment. For each component
type that is located at your facility, you must report the information
specified in paragraphs (q)(2)(i) through (v) of this section. If a
component type is located at your facility and no leaks were identified
from that component, then you must report the information in paragraphs
(q)(2)(i) through (v) of this section but report a zero (``0'') for the
information required according to paragraphs (q)(2)(ii) through (v) of
this section.
* * * * *
    (r) * * *
    (3) * * *
    (ii) Onshore petroleum and natural gas production facilities and
onshore petroleum and natural gas gathering and boosting facilities
must report the information specified in paragraphs (r)(3)(ii)(A) and
(B) of this section, for each major equipment type, production type
(i.e., natural gas or crude oil), and geographic location combination
in Tables W-1B and W-1C to this subpart for which equipment leak
emissions are calculated using the methodology in Sec.  98.233(r).
* * * * *
    (z) * * * If your facility contains any combustion units subject to
reporting according to paragraph (a)(1)(xviii), (a)(8)(i), or
(a)(9)(xii) of this section, then you must report the information
specified in paragraphs (z)(1) and (2) of this section, as applicable.
* * * * *

0
6. Add Table W-1E to subpart W of part 98 in numerical order to read as
follows:

  Table W-1E to Subpart W of Part 98--Default Whole Gas Leaker Emission
  Factors for Onshore Petroleum and Natural Gas Production and Onshore
            Petroleum and Natural Gas Gathering and Boosting
------------------------------------------------------------------------
                                 Emission factor (scf/hour/component)
                             -------------------------------------------
                               If you survey using
    Equipment components       any of the methods    If you survey using
                                     in Sec.            Method 21  as
                                  98.234(a)(1)       specified in  Sec.
                                   through (6)          98.234(a)(7)
------------------------------------------------------------------------
          Leaker Emission Factors--All Components, Gas Service
------------------------------------------------------------------------
Valve.......................                   4.9                   3.5
Flange......................                   4.1                   2.2
Connector (other)...........                   1.3                   0.8
Open-Ended Line 2...........                   2.8                   1.9
Pressure Relief Valve.......                   4.5                   2.8
Pump Seal...................                   3.7                   1.4
Other 3.....................                   4.5                   2.8
------------------------------------------------------------------------
      Leaker Emission Factors--All Components, Light Crude Service
------------------------------------------------------------------------
Valve.......................                   3.2                   2.2
Flange......................                   2.7                   1.4
Connector (other)...........                   1.0                   0.6
Open-Ended Line.............                   1.6                   1.1
Pump........................                   3.7                   2.6
Agitator Seal...............                   3.7                   2.6
Other 3.....................                   3.1                   2.0
------------------------------------------------------------------------
      Leaker Emission Factors--All Components, Heavy Crude Service
------------------------------------------------------------------------
Valve.......................                   3.2                   2.2
Flange......................                   2.7                   1.4
Connector (other)...........                   1.0                   0.6
Open-Ended Line.............                   1.6                   1.1
Pump........................                   3.7                   2.6
Agitator Seal...............                   3.7                   2.6
Other 3.....................                   3.1                   2.0
------------------------------------------------------------------------
1 For multi-phase flow that includes gas, use the gas service emission
  factors.
2 The open-ended lines component type includes blowdown valve and
  isolation valve leaks emitted through the blowdown vent stack for
  centrifugal and reciprocating compressors.
3 ``Others'' category includes any equipment leak emission point not
  specifically listed in this table, as specified in Sec.
  98.232(c)(21) and (j)(10).
4 Hydrocarbon liquids greater than or equal to 20[deg]API are considered
  ``light crude.''
5 Hydrocarbon liquids less than 20[deg]API are considered ``heavy
  crude.''

0
7. Remove Table W-3 to subpart W of part 98 and add Table W-3A and
Table W-3B to subpart W of part 98 in numerical order to read as
follows:

  Table W-3A to Subpart W of Part 98--Default Total Hydrocarbon Leaker
    Emission Factors for Onshore Natural Gas Transmission Compression
------------------------------------------------------------------------
                                 Emission factor  (scf/hour/component)
                             -------------------------------------------
                               If you survey using
     Onshore natural gas       any of the methods    If you survey using
  transmission compression           in Sec.            Method 21 as
                                  98.234(a)(1)       specified in  Sec.
                                   through (6)          98.234(a)(7)
------------------------------------------------------------------------
       Leaker Emission Factors--Compressor Components, Gas Service
------------------------------------------------------------------------
Valve \1\...................                 14.84                  9.51
Connector...................                  5.59                  3.58
Open-Ended Line.............                 17.27                 11.07
Pressure Relief Valve.......                 39.66                 25.42
Meter or Instrument.........                 19.33                 12.39
Other \2\...................                   4.1                  2.63
------------------------------------------------------------------------
     Leaker Emission Factors--Non-Compressor Components, Gas Service
------------------------------------------------------------------------
Valve \1\...................                  6.42                  4.12
Connector...................                  5.71                  3.66
Open-Ended Line.............                 11.27                  7.22

Pressure Relief Valve.......                  2.01                  1.29
Meter or Instrument.........                  2.93                  1.88
Other \2\...................                   4.1                  2.63
------------------------------------------------------------------------
\1\ Valves include control valves, block valves and regulator valves.
\2\ Other includes any potential equipment leak emission point in gas
  service that is not specifically listed in this table, as specified in
  Sec.   98.232(e)(8).

Table W-3B to Subpart W of Part 98--Default Total Hydrocarbon Population
    Emission Factors for Onshore Natural Gas Transmission Compression
------------------------------------------------------------------------
 Population emission factors--gas service onshore   Emission factor (scf/
       natural gas transmission compression            hour/component)
------------------------------------------------------------------------
Low Continuous Bleed Pneumatic Device Vents \1\...                  1.37
High Continuous Bleed Pneumatic Device Vents \1\..                 18.20
Intermittent Bleed Pneumatic Device Vents \1\.....                  2.35
------------------------------------------------------------------------
1 Emission Factor is in units of ``scf/hour/device.''

0
8. Remove Table W-4 to subpart W of part 98 and add Table W-4A and
Table W-4B to subpart W of part 98 in numerical order to read as
follows:

  Table W-4A to Subpart W of Part 98--Default Total Hydrocarbon Leaker
          Emission Factors for Underground Natural Gas Storage
------------------------------------------------------------------------
                                 Emission factor  (scf/hour/component)
                             -------------------------------------------
                               If you survey using
   Underground natural gas     any of the methods    If you survey using
           storage                   in Sec.            Method 21 as
                                  98.234(a)(1)       specified in  Sec.
                                   through (6)          98.234(a)(7)
------------------------------------------------------------------------
          Leaker Emission Factors--Storage Station, Gas Service
------------------------------------------------------------------------
Valve \1\...................                 14.84                  9.51
Connector (other)...........                  5.59                  3.58
Open-Ended Line.............                 17.27                 11.07
Pressure Relief Valve.......                 39.66                 25.42
Meter and Instrument........                 19.33                 12.39
Other \2\...................                   4.1                  2.63
------------------------------------------------------------------------
         Leaker Emission Factors--Storage Wellheads, Gas Service
------------------------------------------------------------------------
Valve \1\...................                   4.5                   3.2
Connector (other than                          1.2                   0.7
 flanges)...................
Flange......................                   3.8                   2.0
Open-Ended Line.............                   2.5                   1.7
Pressure Relief Valve.......                   4.1                   2.5
Other \2\...................                   4.1                   2.5
------------------------------------------------------------------------
\1\ Valves include control valves, block valves and regulator valves.
\2\ Other includes any potential equipment leak emission point in gas
  service that is not specifically listed in this table, as specified in
  Sec.   98.232(f)(6) and (8).

Table W-4B to Subpart W of Part 98--Default Total Hydrocarbon Population
          Emission Factors for Underground Natural Gas Storage
------------------------------------------------------------------------
                                                       Emission factor
          Underground natural gas storage           (scf/hour/component)
------------------------------------------------------------------------
       Population Emission Factors--Storage Wellheads, Gas Service
------------------------------------------------------------------------
Connector.........................................                  0.01

Valve.............................................                   0.1
Pressure Relief Valve.............................                  0.17
Open-Ended Line...................................                  0.03
------------------------------------------------------------------------
       Population Emission Factors--Other Components, Gas Service
------------------------------------------------------------------------
Low Continuous Bleed Pneumatic Device Vents \1\...                  1.37
High Continuous Bleed Pneumatic Device Vents \1\..                 18.20
Intermittent Bleed Pneumatic Device Vents \1\.....                  2.35
------------------------------------------------------------------------
\1\ Emission Factor is in units of ``scf/hour/device.''

0
9. Remove Table W-5 to subpart W of part 98 and add Table W-5A and
Table W-5B to subpart W of part 98 in numerical order to read as
follows:

   Table W-5A to Subpart W of Part 98--Default Methane Leaker Emission
             Factors for Liquefied Natural Gas (LNG) Storage
------------------------------------------------------------------------
                                 Emission factor  (scf/hour/component)
                             -------------------------------------------
                               If you survey using
         LNG storage           any of the methods    If you survey using
                                     in Sec.            Method 21 as
                                  98.234(a)(1)       specified in  Sec.
                                   through (6)          98.234(a)(7)
------------------------------------------------------------------------
      Leaker Emission Factors--LNG Storage Components, LNG Service
------------------------------------------------------------------------
Valve.......................                  1.19                  0.23
Pump Seal...................                  4.00                  0.73
Connector...................                  0.34                  0.11
Other \1\...................                  1.77                  0.99
------------------------------------------------------------------------
      Leaker Emission Factors--LNG Storage Components, Gas Service
------------------------------------------------------------------------
Valve \2\...................                 14.84                  9.51
Connector...................                  5.59                  3.58
Open-Ended Line.............                 17.27                 11.07
Pressure Relief Valve.......                 39.66                 25.42
Meter and Instrument........                 19.33                 12.39
Other \3\...................                   4.1                  2.63
------------------------------------------------------------------------
\1\ ``Other'' equipment type for components in LNG service should be
  applied for any equipment type other than connectors, pumps, or
  valves.
\2\ Valves include control valves, block valves and regulator valves.
\3\ ``Other'' equipment type for components in gas service should be
  applied for any equipment type other than valves, connectors, flanges,
  open-ended lines, pressure relief valves, and meters and instruments,
  as specified in Sec.   98.232(g)(6) and (7).

 Table W-5B to Subpart W of Part 98--Default Methane Population Emission
             Factors for Liquefied Natural Gas (LNG) Storage
------------------------------------------------------------------------
                                                       Emission factor
                    LNG storage                     (scf/hour/component)
------------------------------------------------------------------------
    Population Emission Factors--LNG Storage Compressor, Gas Service
------------------------------------------------------------------------
Vapor Recovery Compressor \1\.....................                  4.17
------------------------------------------------------------------------
\1\ Emission Factor is in units of ``scf/hour/device.''

0
10. Remove Table W-6 to subpart W of part 98 and add Table W-6A and
Table W-6B to subpart W of part 98 in numerical order to read as
follows:

   Table W-6A to Subpart W of Part 98--Default Methane Leaker Emission
               Factors for LNG Import and Export Equipment
------------------------------------------------------------------------
                                 Emission factor  (scf/hour/component)
                             -------------------------------------------
                               If you survey using
    LNG import and export      any of the methods    If you survey using
          equipment                  in Sec.            Method 21 as
                                  98.234(a)(1)       specified in  Sec.
                                   through (6)          98.234(a)(7)
------------------------------------------------------------------------
     Leaker Emission Factors--LNG Terminals Components, LNG Service
------------------------------------------------------------------------
Valve.......................                  1.19                  0.23
Pump Seal...................                  4.00                  0.73
Connector...................                  0.34                  0.11
Other \1\...................                  1.77                  0.99
------------------------------------------------------------------------
     Leaker Emission Factors--LNG Terminals Components, Gas Service
------------------------------------------------------------------------
Valve \2\...................                 14.84                  9.51
Connector...................                  5.59                  3.58
Open-Ended Line.............                 17.27                 11.07
Pressure Relief Valve.......                 39.66                 25.42
Meter and Instrument........                 19.33                 12.39
Other \3\...................                   4.1                  2.63
------------------------------------------------------------------------
\1\ ``Other'' equipment type for components in LNG service should be
  applied for any equipment type other than connectors, pumps, or
  valves.
\2\ Valves include control valves, block valves and regulator valves.
\3\ ``Other'' equipment type for components in gas service should be
  applied for any equipment type other than valves, connectors, flanges,
  open-ended lines, pressure relief valves, and meters and instruments,
  as specified in Sec.   98.232(h)(7) and (8).

 Table W-6B to Subpart W of Part 98--Default Methane Population Emission
               Factors for LNG Import and Export Equipment
------------------------------------------------------------------------
                                                       Emission factor
          LNG import and export equipment           (scf/hour/component)
------------------------------------------------------------------------
   Population Emission Factors--LNG Terminals Compressor, Gas Service
------------------------------------------------------------------------
Vapor Recovery Compressor \1\.....................                  4.17
------------------------------------------------------------------------
\1\ Emission Factor is in units of ``scf/hour/compressor.''

[FR Doc. 2016-27981 Filed 11-29-16; 8:45 am]
 BILLING CODE 6560-50-P