the description of the ``HHV'' term in Equation W-40 to read as
follows: ``Higher heating value of fuel, mmBtu/unit of fuel (in units
consistent with the fuel quantity combusted). For field gas or process
vent gas, you may use either a default higher heating value of 1.235 x
10-3 mmBtu/scf or a site-specific higher heating value.''

C. Summary of Final Revisions to Missing Data Provisions

1. Summary of Final Revisions
    The EPA is finalizing amendments to 40 CFR 98.235, with revisions
from the proposed rule, to clarify the procedures for addressing
missing data. We proposed various missing data procedures for different
types or frequencies of measurement data. For AGR vents, we proposed
that missing quarterly samples must use the average of the value of the
last four quarterly samples. We received comments on how to implement
this requirement when less than four quarters of data are available
(e.g., for new sources). Rather than establishing unique missing data
procedures for this source, we are finalizing a requirement for these
sources to use the ``before'' and ``after'' approach analogous to the
missing data procedures proposed for continuous measurement data.
Similarly, we are also finalizing, with minor revisions from proposal,
the missing data requirements for measurement devices such as
continuous flow monitors and composition analyzers to standardize these
requirements to all measurements required by the rule except for annual
measurement data. For stationary and portable combustion sources, we
are finalizing amendments as proposed to require reporters to use the
missing data procedures in subpart C of part 98.
    As proposed, the EPA is finalizing amendments to allow the use of
best engineering estimates for any parameter that cannot be reasonably
measured or obtained according to the requirements in subpart W for up
to 6 months from the facility's first date of subpart W applicability.
We are also finalizing, with minor revisions from proposal, amendments
to allow the use of best engineering estimates for any parameter that
cannot be reasonably measured or obtained according to the requirements
in subpart W for up to 6 months for facilities that are subject to
subpart W and that acquire new sources from another facility that is
not subject to reporting under subpart W. We originally proposed this
amendment for new wells, but after reviewing the public comments
received, we determined this allowance should be more broadly applied
to any new emissions source acquired by the existing facility from
another facility that is not subject to reporting under subpart W. Only
data and calculations associated with those newly acquired sources fall
under these provisions.
    We are finalizing missing data provisions for annual and biannual
(once every two year) measurements that are similar to the previous
missing data requirements in 40 CFR 98.235 as provided in the subpart W
2010 final rule. These provisions require repeat of the estimation or
measurement as soon as possible, with allowance to use measurements
made after December 31 (in the subsequent year) as substitute values
for the missing data in the reporting year.
    We are not finalizing the reporting requirements for use of missing
data procedures as proposed. In the proposed rule, we required missing
data elements to be reported with significant specificity, including
dates in which substitution values were used, equations in which the
substitute value is used, a description of the circumstances that led
to missing data, a description of the procedure used to develop the
substitute value, the missing data procedure citation claimed, and a
description of how missing data procedures will be avoided in the
future. After reviewing public comments, we determined that reporting
for missing data should more closely align with the requirements in
other Part 98 source categories as guided by the requirements in 40 CFR
98.3(c)(8). We are finalizing reporting requirements to identify the
data element for which missing data procedures were used and the number
of hours (or required measurements) for which missing data procedures
were used. We are also finalizing recordkeeping requirements regarding
the use of missing data procedures to include some of the detail of the
proposed reporting requirements. Specifically, reporters that use
missing data procedures are required to keep a record listing the
emission source type, a description of the circumstance that resulted
in the need to use missing data procedures, the missing data provisions
in 40 CFR 98.235 that apply, the calculation or analysis used to
develop the substitute value, and the substitute value.
2. Summary of Comments and Responses
    This section summarizes the major comments and responses related to
missing data provisions. See the 2014 response to comment document in
Docket Id. No. EPA-HQ-OAR-2011-0512 for a complete listing of all
comments and responses.
    Comment: Several commenters recommended that if BAMM is eliminated
as proposed, then the missing data provisions should be expanded to
include all case-specific monitoring circumstances for which the EPA
has previously reviewed and approved BAMM requests from 2011 through
2014, including (1) vent lines that cannot be safely or feasibly
measured and where acoustic device measurement is not an option; (2)
equipment and piping configurations that cannot be easily modified
without incurring significant expense and operational delays; and (3)
compressor measurement data in a specific mode.
    Response: The EPA has considered the implications of removing BAMM
requirements and commenters' concerns. Although the EPA indicated in
the preamble to the proposed rule

that missing data procedures may provide clarity for reporters who may
have unintentionally missed collecting required data, the missing data
procedures are not intended to replace BAMM or to be used by reporters
as BAMM. In the final rule, the EPA is finalizing multiple revisions to
the rule that address commenter concerns related to BAMM. See Section
II.D of this preamble for further discussion on BAMM.
    Comment: Four commenters suggested that missing data procedures be
expanded beyond ``activity data'' specified in 40 CFR 98.235(g) to
include emissions from locations that are required to be directly
measured and other data such as temperature and pressure. The
commenters asserted there are situations where standard measurement
procedures cannot be conducted and alternatives are necessary. These
commenters asked the EPA to clarify whether activity data include the
data elements similar to those used in Equation W-6 (e.g., atmospheric
pressure; pressure of the gas being discharged; percent of packed
vessel volume that is gas; and the number of dehydrator openings in the
calendar year). Other commenters asked that the missing data provisions
specifically account for compressor vent and rod packing measurements.
These commenters indicated it is not clear whether the EPA intended to
include these measurements in 40 CFR 98.235(g).
    Response: Activity data referred to in 98.235(g) includes data that
are not measured, such as counts of the number of dehydrator openings
in the calendar year. The provisions proposed in 40 CFR 98.233(g) were
intended to cover only activity data values used in emissions
calculations that could not be determined using the methods in 40 CFR
98.233; it does not refer to values that are required to be measured.
In our proposed revisions of the missing data provisions, the EPA
inadvertently omitted missing data procedures for measurements
conducted annually, such as compressor measurements, or biannually,
such as flow measurements of well venting for liquids unloading and
flowback determinations for gas well venting during completions and
workovers with hydraulic fracturing. It was our intent to maintain the
existing missing data procedures for these data elements, which entails
re-measurement of the emissions source. The EPA expects all reporters
to comply with annual measurement requirements as specified in 40 CFR
98.233, unless the missing data provisions for new facilities or newly
acquired sources apply. However, the EPA agrees with the commenters
that missing data procedures are needed for the annual measurements to
accommodate a variety of issues that may arise during sampling and
analysis, including sample breakage during shipping, equipment
malfunction during analysis. Therefore, we have included in this final
rule specific missing data procedures for all estimation and
measurements that are required to be performed annually or biannually.
These provisions are the same as the previous missing data requirements
in 40 CFR 98.235 as provided in the subpart W 2010 final rule. These
provisions require repeat of the estimation or measurement as soon as
possible, with allowance to use measurements made after December 31 (in
the subsequent year) as substitute values for the missing data in the
reporting year.
    Comment: One commenter recommended a clarification of the missing
data provisions for transmission storage tanks in 40 CFR 98.235(b). The
commenter pointed out that although the provisions indicated that
leakage for the entire year should be assumed, it does not provide a
leak rate. The commenter suggested that the provisions allow for the
use of a default rate equal to the leak rate threshold of 3.1 standard
cubic feet (scf) per hour defined in 40 CFR 98.234(a)(5).
    Response: The commenter is correct in noting that the measured
emissions rate is critical to the calculation and that the proposed
missing data procedures in 40 CFR 98.235(b) could be improved for
calculating the emissions. The EPA disagrees that the default value of
3.1 scf per hour referenced by the commenter should be used. The value
of 3.1 scf per hour in 40 CFR 98.234(a)(5) is the minimum level of a
leak that can be detected with the acoustic leak detection device. If a
leak is present, the leak can have a much higher flow rate than this
value. In this case, assigning a default leak rate may grossly
underestimate the emissions. As noted previously in this preamble
section, the EPA has included in this final rule specific missing data
procedures for all estimation and measurements that are required to be
performed annually. These provisions require repeat of the estimation
or measurement as soon as possible, with allowance to use measurements
made after December 31 (e.g., in the subsequent year) as substitute
values for the missing data in the reporting year.
    Comment: Some commenters suggested 40 CFR 98.235(e) should be
revised to allow best engineering estimates for the first reporting
year for facilities that become newly subject to subpart W. One
commenter pointed out that a late year event (e.g., unexpected blowdown
in December) could result in a facility becoming newly subject to the
rule. Two commenters asserted that 6 months was not sufficient and that
a facility would require the use of best engineering estimates for the
initial reporting year because the previously not subject facility
would not have been collecting all data required for subpart W
reporting. These commenters argued that these provisions should be
available to both newly affected facilities and subject facilities with
new emissions sources. Similarly, other commenters requested that 40
CFR 98.235(f) be broadened for all subpart W emission sources (rather
than just wells) for the scenario where there is a change (e.g., new
source, new acquisition) at a subject facility, and the reporter cannot
reasonably acquire necessary data. One commenter provided an example of
adding new compression capacity on-line late in the year at a
transmission or storage facility to meet demands in the winter months.
The commenter stressed that it would be difficult and overly burdensome
to require vent measurements from newly installed compressors. Another
commenter requested that 40 CFR 28.235(f) be applicable to newly
acquired wells whether or not the well was subject to subpart W
previously.
    Response: The EPA contends that 6 months is enough time for a newly
subject facility to begin using the methods required in 40 CFR 98.233.
The reporting rule general provisions at 40 CFR 98.2(h) recommend that
facilities reassess applicability (including revising any relevant
emissions calculations) whenever there is any change that could cause a
facility to meet the applicability requirements of Part 98. Therefore,
facilities which currently operate just under the reporting threshold
for subpart W are aware of what changes would likely cause the facility
to become subject to subpart W and should have an understanding of the
calculation reporting requirements; although reporters may not be aware
when an unexpected blowdown will occur, they would know whether an
unexpected blowdown could cause them to be subject. The reporting rule
general provisions at 40 CFR 98.3(b)(3) also state that if a facility
becomes subject, the first annual report must cover the month during
which the change that caused them to exceed the applicability limit
occurred and the remainder of the year. Therefore, the facility does
not

have to report measurements on the preceding months when no
measurements were conducted. We have clarified 40 CFR 98.235(f) to
specify that these missing data procedures apply to source types that
were acquired from another company and were not previously subject to
subpart W. These sources may require sampling ports to be installed or
other modifications to accommodate measurements required in 40 CFR
98.233.
    The EPA agrees that the proposed provisions in 40 CFR 98.235(e) and
(f) should be extended to all subpart W emission sources, because
issues that make it unreasonable to perform measurements for new wells
may also exist for other subpart W emission sources. Therefore, we are
finalizing these provisions to more broadly apply to ``sources'' rather
than ``wells.''
    The EPA disagrees that the proposed provisions in 40 CFR 98.235(f)
should be extended to sources acquired from other companies that were
previously subject to subpart W. The reporting rule general provisions
in 40 CFR 98.4(h) provide for changes in owners and operators and
provide that such owner or operator shall be responsible for the
representations, actions, inactions, and submissions of the designated
representative and any alternate designated representative of the
facility or supplier. Therefore, reporters are responsible for
gathering data in a timely manner for acquired sources. Also, for
sources acquired from companies that were previously subject to subpart
W, any necessary sampling ports or other modifications would have
previously been made to the equipment to accommodate measurement.
Because facilities typically spend several months planning the
acquisition and installation of new equipment, we anticipate that any
issues can be addressed during this time, before the equipment begins
to operate.
    While we are not extending the missing data provisions proposed in
40 CFR 98.235(e) and (f) to facilities already subject to subpart W, we
acknowledge that there are special cases where new compressors can be
added to an existing facility and it may not be possible to perform an
``as found'' measurement of that new compressor source during the
calendar year, for example, if the compressor is installed in late
December. To address this issue, we have revised the proposed
amendments for compressors at 40 CFR 98.233(o)(1)(i) and (p)(1)(i) to
not require annual measurements of compressors installed after annual
compressor measurements have already been conducted for all existing
compressors at the facility. If not all of the existing compressors at
the facility have been measured, then there is no additional burden
associated with identifying and scheduling a testing crew for measuring
the newly installed compressor. However, if a facility has already
conducted their annual compressor measurements, requiring measurement
of emissions for the newly installed compressor would impose a
significant additional burden and may not be logistically possible
within the calendar year. Therefore, in today's final rule, an annual
measurement of a newly installed compressor would not be required if
annual compressor measurements have already been conducted for all
existing compressors at the facility. In this case, no missing data
provisions are needed or are applicable for these newly installed
compressors.
    Comment: Several commenters took issue with the provisions in 40
CFR 98.235(h) and portions of related reporting requirements in 40 CFR
98.236(bb). The commenters objected to reporting a description of the
unique or unusual circumstance that led to missing data use and a
description of how the owner or operator will avoid the use of missing
data in the future. The commenters argued that this would create an
unneeded burden on reporters, go beyond the requirements of a reporting
program, and are an overreach of the EPA's authority. Other industries
subject to Part 98 are not required to this level of detail. One
commenter also asserted that aggregation of missing data values is
appropriate.
    Response: Reporting elements for the missing data provisions are
necessary for the EPA to understand what missing data substitute values
were used; however, we agree with the commenter that the level of
detail required in the proposed reporting requirements could become
burdensome, especially for continuously monitored parameters. We
reviewed the reporting requirements associated with the use of missing
data procedures in the general provision 40 CFR 98.3(c)(8) and other
subparts in Part 98. Although we disagree that the proposed missing
data reporting requirements go beyond the requirements of a reporting
program or is an overreach of the EPA's authority, we recognize that
missing data can occur, such as due to calibration checks that indicate
an instrument needs to be recalibrated. After considering the proposed
reporting requirements in light of the comments received and the
reporting provisions in other subparts, we determined that revisions
were needed to the proposed missing data reporting requirements. In
this final rule, we are requiring reporting of the use of missing data
procedures following the general provision requirements in 40 CFR
98.3(c)(8), except we are providing for the reporting of number of
times missing data procedures were used for an element that is not
based on continuously monitored parameters.
    Comment: One commenter noted that the missing data procedures
proposed in 40 CFR 98.235(a) should be amended to accommodate new AGR
vents that may not have four previously taken samples available.
Another commenter indicated that 40 CFR 98.235(d) poses a problem where
``before'' or ``after'' values are not available for a data element
that requires measurement. The commenter asserted that instances where
a ``before'' or ``after'' value is not available for substitution
require additional flexibility to enable compliance. The commenter
provided, as an example, a situation where information from a third-
party equipment operator, such as a third-party operated dehydrator, is
not received and no data are available to substitute. The commenter
also noted that there may be instances where a well completion in a
sub-basin category/county/well-type combination is a single unique well
and the measurement equipment necessary to measure flowback or
calculate flowback malfunctions. The commenter argued that in this
case, a reporter will not have ``before'' data to substitute.
    Response: With respect to the missing data procedures for AGR
vents, we agree with the commenter that additional clarification is
needed, particularly to address new AGR vents that do not have four
previous quarterly samples. In considering potential clarifications for
the missing data procedures for AGR vents in light of the various
scenarios of data availability, the missing data procedures for this
source mirrored the procedures proposed in 40 CFR 98.235(d).
Furthermore, we determined that the use of the average of a ``before''
and ``after'' sample would provide as good an estimate of the missing
data as the average of four ``before'' samples. Therefore, we are
generalizing the proposed missing data procedures in 40 CFR 98.235(d)
to apply to all measurements that are required to be performed
quarterly or more frequently.
    The provisions proposed at 40 CFR 98.235(d) include specific
provisions that can be used to determine the missing value in the
absence of a ``before'' or ``after'' measurement. We find that the
proposed procedures are reasonable for any data element that is

required to be monitored quarterly or more frequently. The proposed
provisions of 40 CFR 98.235(d) are not meant to address measurement
data that are required annually or biannually or situations such as the
supply of information by third-party vendors. Reporters should know
what information is needed for the annual reports. If reporters elect
to use third-party vendors for certain services, the information needed
for the annual reports may be specified in the third-party contract or
agreement to ensure the necessary information is provided. We are not
including any missing data provision in the final rule to allow for use
of third-party operators that do not provide the required information
needed for determining the emissions from dehydrators or other
emissions sources.

D. Summary of Final Amendments to Best Available Monitoring Methods

1. Summary of Final Revisions
    In this final rule, the EPA is removing all prior provisions in 40
CFR 98.234(f) for BAMM as proposed, but we are also adding transitional
BAMM provisions for the 2015 calendar year after considering public
comments. Specifically, we are revising 40 CFR 98.234(f) to provide
short-term transitional BAMM for reporters who are subject to new
monitoring or measurement requirements as part of these final
amendments. Reporters have the option of using BAMM from January 1,
2015, to March 31, 2015, for certain parameters that cannot reasonably
be measured according to the monitoring and QA/QC requirements of 40
CFR 98.234. Specifically, the transitional 2015 BAMM provisions cover
the following data:
     Well-related measurement data that cannot reasonably be
measured for well venting for liquids unloading and gas well venting
during well completions and workovers with hydraulic fracturing, from
wells not previously measured.
     Reciprocating compressor blowdown valve, isolation valve,
and rod packing venting from manifolded vents, when conducting ``as
found'' measurements according to revised 40 CFR 98.233(p)(4) or
(p)(5).
     Centrifugal compressor blowdown valve, isolation valve,
and wet seal oil degassing venting from manifolded vents, when
conducting ``as found'' measurements according to revised 40 CFR
98.233(o)(4) or (o)(5).
    For these parameters, reporters have the option to use BAMM from
January 1, 2015, to March 31, 2015, without seeking prior EPA approval.
Reporters will also have the opportunity to request an extension for
the use of BAMM beyond March 31, 2015; those owners or operators must
submit a request to the Administrator by January 31, 2015. The EPA is
not providing transitional BAMM for these revised requirements beyond
December 31, 2015. The provision of 3 months of automatic transitional
BAMM will allow reporters to prepare for data collection while
automatically being able to use BAMM, which is consistent with BAMM
schedules in prior Part 98 rulemakings. This additional time for
reporters to comply with the revised monitoring methods in subpart W
will allow facilities to install the necessary monitoring equipment
during other planned (or unplanned) process unit downtime, thus
avoiding process interruptions.
    We are also removing and reserving 40 CFR 98.234(g). As described
in the preamble to the proposed rule, we intended to remove and reserve
this section but the removal of this section was not included in the
regulatory text. These removed provisions are specific to the 2011 and
2012 reporting years, and the removal of this provision does not impact
the reporting requirements for subsequent reporting years.
2. Summary of Comments and Responses
    This section summarizes the major comments and responses related to
best available monitoring methods. See the 2014 response to comment
document in Docket Id. No. EPA-HQ-OAR-2011-0512 for a complete listing
of all comments and responses.
    Comment: Three commenters supported the removal of BAMM for natural
gas distribution facilities beginning in the 2015 calendar year. One
commenter stated that replacing BAMM with explicit reporting
requirements for petroleum and natural gas systems will reduce
transaction costs, improve compliance, improve access to information
about the oil and gas sector, and increase confidence in the rule. A
second commenter believed that by clarifying the reporting emissions
from natural gas distribution facilities, there should be no need to
use BAMM after January 1, 2015. A third commenter pointed out that BAMM
was originally a transitional tool, and other industry-specific
subparts of Part 98 have eliminated BAMM. The commenter stated that the
use of BAMM in 2012 created difficulties in comparing data across
facilities and understanding discrepancies between GHG and other
inventories. The commenter supported the addition of expanded missing
data procedures and compliance pathways for facilities to use in the
future. The commenter suggested that if operators require more
flexibility than the ones EPA has proposed, that flexibility should be
incorporated through a rulemaking effort rather than BAMM requests.
    Eight commenters disagreed with the removal of BAMM beginning in
the 2015 calendar year. Several commenters stated that eliminating BAMM
would compromise compliance of impacted sources, especially in
instances when it is not feasible to obtain a required measurement or
where a direct measurement may be unsafe. These commenters requested
the ongoing availability of BAMM or a revision of the missing data
procedures for those instances where a reporter demonstrates a
legitimate need.
    Commenters pointed out that access to alternative methods is
necessary for regulations. Some of the commenters pointed out that the
EPA has allowed alternative compliance and monitoring methods in other
regulatory programs (e.g., NSPS in 40 CFR part 60, National Emission
Standards for Hazardous Air Pollutants (NESHAP) in 40 CFR part 63, and
the Acid Rain Program in 40 CFR part 75) and urged the EPA to create a
replacement, such as robust missing data provisions, for BAMM if it is
eliminated. Other commenters stated that subpart W includes additional
and more complex measurements than other Part 98 source categories.
Some commenters expressed the importance of BAMM for sources that
subsequently become subject to GHG reporting or where unpredictable
future events occur. One commenter considered the flexibility of
alternative methods to be important in the development of new
technology and asked that the EPA should consider allowances in those
cases. The commenter provided example scenarios in which the commenter
stated that BAMM or an alternative method should be required, although
the scenarios are not necessarily ``unique or unusual,'' such as vent
lines that are unsafe to access and are unable to be assessed with an
acoustic device, operating modes that are rarely used, and facilities
where a late year addition of a new source precludes the ability to
gather data.
    Another commenter explained that future changes in operation or
equipment may cause the facility to exceed the reporting threshold or
create circumstances in which emission points meet the subpart W
criteria, though that may not be known until the facility is surveyed.
The commenter stated that

there may be time to resolve the situation before the monitoring
deadline, but BAMM or a robust missing data provision would be needed.
Two commenters asked that BAMM be allowed for newly acquired wells that
were previously reported by prior owners and wells that have never
reported, as both situations require the same level of effort to
comply.
    Three commenters requested at least a 6-month transitional BAMM
following the final rule. The commenters requested adequate time to
implement changes following the final rule. One commenter stated that a
transitional BAMM of 6 months would allow flexibility to reporters,
provide time for clarifications, allow for the development for the
required systems, and accommodate issues regarding situations beyond
the facility's control which require BAMM. Another commenter stated
that developing processes for monitoring data or activities that have
never before been subject to federal or state reporting may take
significant time and effort. The commenter pointed out that until the
final rule has been issued, reporters will not be able to determine
what is required and will not know if BAMM is needed. Another commenter
stated that if BAMM is not extended, small operators without the
resources to quickly implement the rule would be unfairly
disadvantaged.
    Response: The EPA has considered the concerns raised by commenters
in the development of this final rule. We are removing the prior BAMM
requirements in 40 CFR 98.234(f) because we have determined that these
provisions, which applied broadly to circumstances in which data
collection methods did not meet safety regulations, were technically
infeasible, or were counter to state, local, or federal regulations,
are no longer necessary to comply with the final rule. As one commenter
noted, BAMM was originally included in Part 98 as a transitional tool,
and all other industry-specific subparts of Part 98 have eliminated
BAMM from their monitoring options. The revisions in this final rule
will resolve the need for BAMM for the scenarios mentioned above for
subpart W and can, therefore, bring this subpart into alignment with
the monitoring provisions in other industry-specific subparts by
removing the current BAMM provisions. In the development of this final
rule, the EPA reviewed BAMM request submittals for the 2014 reporting
year. In our review, the EPA found that the sources with the most
frequent BAMM requests included centrifugal compressors, reciprocating
compressors, blowdown vent stacks, and combustion emissions, which are
addressed in this rulemaking. The most common concerns raised in BAMM
requests were associated with technical infeasibility including
concerns related to having to shut down a facility to install access
ports to conduct compressor measurements. Other concerns related to
compressors routed to a flare, manifolded lines, and compressor vents
that were unsafe or inaccessible to measure. As discussed in Section
II.B.10 of this preamble, we are making several revisions in this final
rule that will allow for the testing of these compressor vents. First,
we are clarifying that operators do not have to shut a facility down
for the sole purpose to test a compressor in its non-operating mode,
but that the measurement must be made at the next scheduled shutdown
that requires a compressor to be taken off-line for planned or
scheduled maintenance. These provisions reduce the burden on reporters
to schedule a shutdown solely for the purposes of conducting
measurements. The EPA has also provided the option for facilities to
conduct continuous measurements using a permanent meter. Next, we are
providing for reporters to conduct a single annual ``as found''
measurement for manifolded compressors routed to a common vent, in lieu
of a measurement for each individual compressor manifolded to the
common vent. We are also allowing the use of an IR camera for pre-
screening of emissions from blowdown valves on compressors in operating
mode or standby-pressurized mode and for isolation valves on
compressors in not-operating-depressurized mode. The option to use an
IR camera to screen for emissions, in addition to the current allowance
for use of an acoustic measurement device, eases the burden on
facilities with inaccessible or unsafe-to-measure valves. Finally, for
compressors routed to a flare, we are finalizing provisions to allow
operators to calculate and report emissions with other flare emissions.
In this case, reporters are no longer required to sample compressors
routed to a flare individually.
    The EPA is also addressing the most common scenarios for which BAMM
was previously requested for other emission sources. For example, for
blowdown vent emissions, the EPA previously approved BAMM requests for
reporting data by unique physical volume. In this final rule, we are
revising the reporting of blowdown emissions to aggregate emissions by
equipment type, as discussed in Section II.B.6 of this preamble.
Similarly, for well venting for liquids unloading, the final rule
allows for annualizing of venting data to account for situations where
it was not feasible to gather vent hours or the number of unloadings
from all controllers on January 1 or December 31, and it provides
alternatives to determining the shut-in pressure required in Equation
W-8. We have incorporated revisions in this final rule to address BAMM
concerns for onshore production tanks and well completions and
workovers. Additionally, we are finalizing missing data procedures that
add clarity and specificity in how to treat and report missing data,
including continuous measurements, periodic measurements and activity
data. These missing data procedures are not intended to replace BAMM,
however, they provide clarity for reporters who may have
unintentionally missed collecting required data. These missing data
procedures would also apply to facilities for which changes in
operation or equipment may cause the facility to exceed the reporting
threshold or result in creating circumstances in which emission points
meet the subpart W criteria, as well as for newly acquired sources that
were not previously reported under subpart W. We also note that there
have been previous BAMM requests in which facilities noted technical
concerns including instances where equipment modifications or
installations were necessary. By the 2015 reporting year, facilities
will have had four years to implement any necessary changes in order to
fully comply with subpart W, which we have determined to be sufficient
time to make any equipment modifications or installations. Therefore,
we are not including BAMM provisions for these scenarios in this final
rule.
    Regarding the comment that other regulatory programs allow
alternative compliance and monitoring methods, the EPA acknowledges
that the provisions of NSPS and NESHAP allow facilities to request
alternative monitoring and testing methods. However, the NSPS and
NESHAP provisions typically require that specific monitoring methods be
used (e.g. EPA Method 18 for gas compositional analysis), and they do
not allow facilities to use alternative monitoring and testing methods
without the method first being approved by the EPA. The EPA has
provided a great deal of flexibility in the methods allowed in subpart
W, such as certain provisions that allow the use of standard methods
published by consensus-based standard organizations and that allow the
use of

industry standard practice. Given the flexibility in the methods
allowed under Part 98, we do not agree with the commenters.
    Although we are removing the current BAMM provisions of 40 CFR
98.234(f), the final rule introduces new short-term transitional BAMM
provisions for certain parameters for the 2015 calendar year. The EPA
agrees with commenters that some facilities may need to obtain the
necessary equipment to conduct measurements as required under the
revised calculation methods in this final rule. Thus, under the final
rule, reporters have the option of using BAMM for certain parameters
that cannot be reasonably measured according to the monitoring and QA/
QC requirements of 40 CFR 98.234. For example, we are revising the
emission estimation methods for well completions and workovers from
wells with hydraulic fracturing to separate reporting by well
completions and workovers and by the sub-basin and well-type
combination. In some cases, we expect reporters will be required to
measure existing wells of a well-type combination for which they have
not previously reported separately. In this case, reporters have the
option to use BAMM for well-related data (i.e., initial and average
flowback rates for Calculation Method 1 or pressures upstream and
downstream of the choke for Calculation Method 2). Other situations
where the final rule provides an option to use BAMM in the 2015
calendar year are for determining vented gas flow when using
Calculation Method 1 to estimate emissions from liquids unloading, and
for determining vented emissions from compressor sources that are
manifolded.
    In some cases, although we are revising emissions calculation
methods in the final rule, we are not providing the BAMM option because
the underlying measurement methods have not changed. For example,
although we have separated the calculation of emissions from
completions and workovers from wells without hydraulic fracturing in 40
CFR 98.233(h), reporters are still collecting the same well data and
measurements. We are not providing BAMM in this case or in similar
cases where reporters would not be required to change their data
collection methods.
    We are not providing the BAMM option for parameters in revised
calculation methods where the rule already provides alternatives to
direct measurements. For example, the final rule requires facilities in
the onshore natural gas transmission compression, underground natural
gas storage, LNG storage, and LNG import export industry segments to
report emissions from flares based on using the calculation methods for
flare stacks. BAMM is not needed in this case because 40 CFR
98.233(n)(1) specifies that flare gas flow may be estimated using
engineering calculations based on process knowledge, company records,
and best available data. Similarly, 40 CFR 98.233(n)(2) specifies that
as an alternative to using a continuous gas composition analyzer on the
flare gas, a reporter in the four industry segments now required to
report flare emissions may use a representative composition determined
by engineering calculation based on process knowledge and best
available data. The BAMM option also is not being provided for activity
data such as completion or workover counts and venting or operating
time because the final rule does not specify monitoring equipment that
must be used for measuring these parameters.
    The final rule allows reporters to use BAMM for the specified
parameters during the January 1, 2015 to March 31, 2015 time period
without seeking prior EPA approval. By automatically allowing BAMM
until March 31, 2015, this schedule allows additional time following
the publication of the final rule for reporters to prepare for data
collection and install the necessary monitoring equipment. The final
rule also provides for reporters the option to request an extension for
the use of BAMM beyond March 31, 2015, but no further than December 31,
2015. Reporters who request an extension must submit a request to the
Administrator by January 31, 2015, and demonstrate to the
Administrator's satisfaction that it is not reasonably feasible to
acquire, install, and operate a required piece of monitoring equipment
by April 1, 2015, to receive approval to use BAMM beyond March 31,
2015. In these cases, the Administrator will only approve BAMM for the
parameters specified in Section II.D.1 of this preamble. We anticipate
that the number of BAMM requests approved for the 2015 calendar year
will be limited and will not greatly impact the quality of the data
collected in 2015.

E. Summary of Final Additions of New Data Elements and Revisions to
Reporting Requirements

1. Summary of Final Revisions
    We are finalizing the addition of several data elements to 40 CFR
98.236, with revisions from the proposed rule based on review of
comments and other considerations. Although the EPA received comments
objecting to the proposed addition of these data elements, these new
data elements are based on data that are already collected by the
reporter or are readily available to the reporter. The reporting of
these data elements will improve the quality of the data reported,
improve the verification of reported emissions, and reduce the amount
of correspondence with reporters that is associated with follow-up and
revision of annual reports.
    After proposal, we determined that some proposed data elements
could be removed to lessen reporter burden. For offshore production
facilities, the final rule requires reporting of the total quantity of
oil handled at the offshore platform, which includes the quantity from
blended oil/condensate streams; this reporting element replaces the
proposed requirements to report the amount of oil and the amount of
condensate separately. Additionally, we are not finalizing the proposed
requirements to report the model name, description, and installation
year for each compressor.
    As a result of comments received on the proposed rule, we are
adding requirements to report two data elements for centrifugal and
reciprocating compressors. Affected facilities with centrifugal or
reciprocating compressors will be required to indicate whether the
measured volume of flow from the compressor includes blowdown
emissions, according to 40 CFR 98.236(o)(4)(iii) and 40 CFR 98.236
(p)(4)(iii), respectively.
2. Summary of Comments and Responses
    This section summarizes the major comments and responses related to
the addition of new reporting requirements in 40 CFR 98.236(aa). See
the 2014 response to comment document in Docket Id. No. EPA-HQ-OAR-
2011-0512 for a complete listing of all comments and responses.
    Comment: One commenter questioned the proposal's requirements to
report information that does not address emissions but instead requires
ancillary information such as compressor ratings. The commenter
considered these new measurement and reporting requirements to go
beyond the authority of the EPA under CAA Sections 114 and 208, making
the changes arbitrary and capricious if finalized. The commenter
considered the proposed reporting requirement changes to be an
overreach for an emissions reporting program and points out that 40 CFR
98.236(aa) in particular appears to be using Part 98 as a vehicle to
construct detailed profile of

the oil and gas production sector. The commenter considered the
proposed changes to unnecessarily expand the measurements and reporting
requirements from the existing Part 98 and points out examples.
    Multiple commenters provided examples of data elements that they
stated are not within the scope of Part 98 because they are not
directly related to emissions quantification or are redundant: For
transmission storage tank vent stack, whether scrubber dump leakage is
occurring for the underground storage vent--Sec.  98.236(k)(l)(iii);
year compressor was installed--Sec.  98.236(p)(1)(xiv); compressor
model name and description-- Sec.  98.236(p)(1)(xv); date of last rod
packing--Sec.  98.236(p)(1)(xvi); average time surveyed components were
found leaking and operational--Sec.  98.236(q)(2)(iii); average
upstream pipeline pressure, psig--Sec.  98.236(aa)(4)(iv); average
downstream pipeline pressure, psig--Sec.  98.236(aa)(4)(v); quantity of
gas injected into storage--Sec.  98.236(aa)(5)(i); quantity of gas
withdrawn from storage--Sec.  98.236(aa)(5)(ii); number of
compressors--Sec.  98.236(aa)(4)(ii); total compressor power rating for
all compressors combined, hp--Sec.  98.236(aa)(4)(iii); and total
storage capacity for underground natural gas storage facilities--Sec.
98.236(aa)(5)(iii).
    One commenter stated that the EPA should explain or justify the
need for addition of these data elements. Multiple commenters stated
that the new reporting requirements are not relevant for quantifying
emissions and developing this information in order to report represents
a substantial burden.
    Response: The EPA disagrees with commenters that the proposed data
elements are beyond the authority of the EPA under CAA section 114. CAA
section 114 authorizes the EPA to gather the information under this
rule. Specifically, section 114 provides for the gathering of
information from direct sources of GHG emissions, as long as that
information is for purposes of carrying out any provision of the CAA.
CAA section 208 applies to mobile sources, which are not covered by
subpart W.
    The additional reporting requirements included in this final rule
provide production, capacity, and operational information for sources
subject to subpart W and are similar to the data collected under other
subparts of Part 98. These data elements are useful for the
verification of existing data. For example, production, capacity, or
operational information may be used to normalize the data collected and
adequately characterize emissions sources. Therefore, the EPA is
finalizing these reporting requirements as proposed, with minor
clarifications. Further information on the final changes to the
reporting section may be found in the memorandum, ``Final Revisions to
the Subpart W Reporting Requirements in the ``Greenhouse Gas Reporting
Rule: 2014 Revisions and Confidentiality Determinations for Petroleum
and Natural Gas Systems; Final Rule'' in Docket Id. No. EPA-HQ-OAR-
2011-0512.

III. Confidentiality Determinations

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

    In the proposed rule, we assigned new or revised data elements to
the appropriate direct emitter data categories created in the 2011
Final CBI Rule based on the type and characteristics of each data
element. For 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 revised data element. For data elements assigned to the ``Unit/
Process `Static' Characteristics that Are Not Inputs to Emission
Equations'' and ``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. We also
proposed individual confidentiality determinations for 11 new or
substantially revised data elements without making a data category
assignment and we proposed to revise the confidentiality determination
for one existing subpart W data element. Refer to the preamble to the
proposed rule (79 FR 13394, March 10, 2014) for additional information
regarding the proposed confidentiality determinations.
    With consideration of the data provided by commenters, the EPA is
finalizing the confidentiality determinations as proposed for all but 7
of the new and substantially revised data elements that were proposed.
Specifically, the EPA is finalizing the proposed decision to require
each of the new data elements and the one existing data element for
which we revised the confidentiality determination be designated as
``not CBI'', with the exception of seven new data elements for which we
have subsequently identified potential confidentiality concerns, as
discussed in this section. The seven data elements with revised
confidentiality determinations apply to onshore natural gas plants and
natural gas transmission facilities.
    For onshore natural gas plants, the EPA has revised the
determination for the following four data elements: The quantity of
natural gas received at the gas processing plant in the calendar year
(reported under 40 CFR 98.236(aa)(3)(i)), the quantity of processed
(residue) gas leaving the gas processing plant (reported under 40 CFR
98.236(aa)(3)(ii)), the quantity of natural gas liquids (NGL) (bulk and
fractionated) received (reported under 40 CFR 98.236(aa)(3)(iii)), and
the quantity of NGL (bulk and fractionated) leaving the plant (reported
under 40 CFR 98.236(aa)(3)(iv)). In the proposal, we indicated that we
designated the annual quantity of natural gas received at a gas plant
and the annual quantity of residue gas leaving a gas plant to be ``not
CBI'' because the average annual flow and plant utilization rate are
published on the Energy Information Administration's (EIA's) Web site
and are already in the public domain. However, upon reexamination we
determined that reporting to EIA of the amount of natural gas received
is less frequent than that required under subpart W and we have not
identified any reliable public sources of the quantity of residue gas
produced. Thus, we have decided to maintain the annual quantity of
natural gas received at gas plants and the annual quantity of processed
(residue) gas leaving gas plants as confidential.
    We indicated in the proposal that the two NGL data elements were
aggregated values for all NGL received and all NGL supplied by a
natural gas processing plant. We also explained that this information
would not cause competitive harm to reporters because the data for
individual NGL products (which would be likely to cause competitive
harm) would not be disclosed. While most plants receive and supply
several different NGL products, we have identified a few plants that
receive and/or supply only one NGL product. For example, some plants
remove only ethane from the natural gas received. For this subset of
plants, the quantity to be reported under subpart W is identical to the
quantity reported under subpart NN, which the EPA determined to be CBI
(see 76 FR 30782, May 26, 2011). Thus, the EPA has decided not to make
a confidentiality determination for 40 CFR 98.236(aa)(3)(iii) and
(aa)(3)(iv).

The confidentiality status of these data elements will be evaluated on
a case-by-case basis, in accordance with the existing CBI regulations
in 40 CFR part 2, subpart B, upon receipt of a public request for these
data elements.
    For the natural gas transmission sector, the EPA has revised the
confidentiality determination in this action for three data elements:
The quantity of gas transported through a compressor station (reported
under 40 CFR 98.236(aa)(4)(i)) and the average upstream and downstream
pressures (reported under 40 CFR 98.236(aa)(4)(iv) and (v),
respectively). We proposed that these data elements be designated as
``not CBI.'' We noted that the natural gas transmission sector was
heavily regulated by the Federal Energy Regulatory Commission (FERC)
and state commissions due to a lack of competition between companies.
We further noted that FERC controls pricing, sets rules for business
practices, and is responsible for approving the location, construction,
and operations of companies operating in this sector. However, we
received comments from this industry sector noting that FERC Order 636
had introduced greater competition to this sector and that some
companies charge customers less than the FERC approved rates because of
competitive market pressures. The three data elements identified above
would provide information on the quantity of gas transported by a
specific pipeline. This information may potentially cause competitive
harm to some pipeline companies operating in more competitive market
areas. Since the determination would depend on the particular market
conditions for each company, the EPA was not able to make a
determination for these data elements that would apply for all
reporters. Thus, the EPA has decided not to make a confidentiality
determination for 40 CFR 98.236(aa)(4)(i), (iv) and (v). The
confidentiality status of these data elements will be evaluated on a
case-by-case basis, in accordance with the existing CBI regulations in
40 CFR part 2, subpart B, upon receipt of a public request for these
data elements.
    The EPA received several comments questioning the proposed
determination that several new or revised data elements should be
treated as non-confidential. Specifically, we received comments
requesting that the EPA classify certain data elements associated with
exploratory wells (delineation and wildcat wells) as CBI for a period
of at least 24 months from the start of exploration. These comments and
the EPA's responses are summarized in Section III.B of this preamble.
Based on consideration of these comments and consistent with the EPA's
previous decisions related to exploratory wells under Part 98 (79 FR
63750, October 24, 2014), the EPA is revising the final rule to provide
reporters with the option to delay reporting of 12 data elements for
two reporting years in situations where exploratory wells are the only
wells in a sub-basin. For a given sub-basin, in situations where
wildcat wells and/or delineation wells are the only wells in a sub-
basin that can be used for the required measurement, the following data
elements associated with the delineation or wildcat well may be delayed
for two reporting years: (1) Cumulative flowback time for each sub-
basin (40 CFR 98.236(g)(5)(i)); (2) measured flowback rate for each
sub-basin (40 CFR 98.236(g)(5)(ii)); (3) average daily gas production
rate for all completions without hydraulic fracturing in the sub-basin
without flaring (40 CFR 98.236(h)(1)(iv)); (4) average daily gas
production rate for all completions without hydraulic fracturing in the
sub-basin with flaring (40 CFR 98.236(h)(2)(iv)); (5) if using
Calculation Method 1 or 2 for atmospheric storage tanks, the total
annual gas-liquid separator oil volume that is sent to atmospheric
storage tanks in the sub-basin, in barrels; (6) if using Calculation
Method 3 for atmospheric storage tanks, the total annual oil throughput
that is sent to atmospheric tanks in the basin (40 CFR
98.236(j)(2)(i)(A)); (7) if oil well testing is not performed where
emissions are not vented to a flare, the average flow rate in barrels
of oil per day for well(s) tested (40 CFR 98.236(l)(1)(iv); (8) if oil
well testing is performed where emissions are vented to a flare, the
average flow rate in barrels of oil per day for well(s) tested (40 CFR
98.236(l)(2)(iv)); (9) if gas well testing is performed where emissions
are not vented to a flare, average annual production rate in actual
cubic feet per day for well(s) tested (40 CFR 98.236(l)(3)(iii)); (10)
if gas well testing is performed where emissions are vented to a flare,
average annual production rate in actual cubic feet per day for well(s)
tested. (40 CFR 98.236(l)(4)(iii)); (11) volume of oil produced in the
calendar year during the time periods in which associated gas was
vented or flared (40 CFR 98.236(m)(5)); and (12) total volume of
associated gas sent to sales in the calendar year during time periods
in which associated gas was vented or flared (40 CFR 98.236(m)(6))).
    Six of the 12 data elements for which reporting may be delayed by 2
years are inputs to emission equations and the EPA provided the same
option in the EPA's previous decisions related to exploratory wells
under Part 98 (79 FR 63750, October 24, 2014). Five of the 12 data
elements are inputs only when the applicable data are related to a
single well (40 CFR 98.236(g)(5)(i), (h)(1)(iv), (h)(2)(iv), (m)(5),
and (m)(6)), and one data element is never an input (40 CFR
98.236(j)(2)(i)(A)). The EPA decided to treat all early disclosure
concerns related to exploratory wells consistently throughout subpart W
by providing the option to delay reporting by 2 years to all 12 data
elements. For the six data elements that are not always inputs, the
finalized confidentiality determinations of ``not CBI'' apply in
situations where the data elements are not an input to an equation.
Specifically, the ``not CBI'' determination applies to all situations
that involve multiple non-exploratory wells or a mix of exploratory and
non-exploratory wells, and the ``not CBI'' determinations also will
apply to data elements related to multiple exploratory wells once the
data are reported to the EPA following the 2 year delay. For the
situations when the data elements are used as inputs to equations, the
EPA is assigning them to the ``Inputs to Emission Equations'' data
category and is not making confidentiality determinations for these
data.
    In response to public comments, the EPA has added eight new data
elements related to compressors as reporting requirements and has
assigned them to the ``Unit/Process `Static' Characteristics That Are
Not Inputs to Emission Equations'' data category. Two of the new data
elements require reporters to indicate whether compressor blowdown
emissions are included in the measured volume of flow from compressor
sources that are monitored continuously. Four of the new data elements
require reporters to indicate whether measurements for manifolded
groups of compressor sources are located prior to or after comingling
with non-compressor emissions. These six data elements apply to both
centrifugal compressors and reciprocating compressors, and they are
located in 40 CFR 98.236(o)(3)(i)(F), (o)(4)(iii), (o)(4)(iv),
(p)(3)(i)(F), (p)(4)(iii), and (p)(4)(iv). For each centrifugal and
reciprocating compressor equipped with blind flanges, the other two new
data elements require reporters to provide the dates when the blind
flanges were in place, and these elements are located in 40 CFR
98.236(o)(1)(x) and (p)(1)(xii). All eight of the new data elements are
the same type of data as other data elements included in this category
in

the March 2014 proposal such as the data element that requires
reporters to indicate whether any compressor source emissions are
routed to a flare. Like other data elements in this category, the new
data elements do not vary with time or with the operation of the
compressor. Additionally, the new data elements describe only an aspect
of the compressor design and emissions handling technique that reveals
no sensitive information that would be likely to cause substantial harm
to any type of natural gas facility. The March 2014 proposal addressed
the same type of data elements. We conclude that it is appropriate to
assign the data elements to this data category and finalize our
determination that these data elements are ``not CBI'' in this action.
    The EPA has determined that we inadvertently omitted proposing
confidentiality determinations for 12 new data reporting elements. The
measured scrubber dump valve leak rate vented directly to atmosphere
(40 CFR 98.236(k)(2)(ii)), the measured scrubber dump valve leak rate
vented to flare (40 CFR 98.236(k)(3)(ii)), and the annual
CO2 and CH4 emissions from above grade metering-
regulating stations that are not above grade transmission-distribution
transfer stations (40 CFR 98.236(r)(2)(v)(A) and (r)(2)(v)(B),
respectively) are data representing emissions to the atmosphere. The
March 2014 proposal addressed numerous similar elements and assigned
them to the ``Emissions'' data category, which has a categorical
confidentiality determination of ``not CBI.'' We conclude that it is
appropriate to assign the four previously omitted data elements to the
``Emissions'' data category and finalize our determination that these
data elements are ``not CBI'' in this action.
    Five of the new data elements for which we did not propose
confidentiality determinations in the proposed rule are similar to data
elements that were assigned to the ``Unit/Process Operating
Characteristics That are Not Inputs to Emission Equations'' data
category. For example, the type of control device for emissions from
glycol dehydrators with an annual average daily natural gas throughput
less than 0.4 MMscf per day (40 CFR 98.236(e)(2)(iii)) is the same as
the data element in 40 CFR 98.236(e)(3)(i) for reporting the type of
control device used to control emissions from dehydrators that use
desiccant. The number of atmospheric tanks in the sub-basin that did
not control emissions with flares (40 CFR 98.236(j)(2)(ii)(B)) and the
number of atmospheric tanks in the sub-basin that controlled emissions
with flares (40 CFR 98.236(j)(2)(iii)(B)) are comparable to the data
elements in 40 CFR 98.236(e)(2) and (e)(3) for the counts of
dehydrators that vent to atmosphere, flare, vapor recovery, or other
types of control devices. The duration of time that a scrubber dump
valve leak occurred (40 CFR 98.236(k)(2)(iii)) and the duration of time
that flaring of a scrubber dump valve leak occurred (40 CFR
98.236(k)(3)(iii)) are comparable to the data element in 40 CFR
98.236(j)(3)(ii) for the total time that dump valves on gas-liquid
separators did not close properly. Furthermore, as we noted in the
discussion of the confidentiality determination for 40 CFR
98.236(j)(3)(ii) in the preamble to the proposed rule, because the time
period during which a dump valve is malfunctioning provides little
insight into maintenance practices or the nature or cost of repairs
that are needed, public disclosure of such information would not be
likely to cause substantial competitive harm to reporters. The
finalized confidentiality determinations for all of the data elements
that are comparable to the five data elements that were inadvertently
omitted from the analysis at proposal are ``not CBI.'' We conclude that
it is appropriate to assign the five previously omitted data elements
to the ``Unit/Process Operating Characteristics That are Not Inputs to
Emission Equations'' data category and finalize our determination that
these data elements are ``not CBI'' in this action.
    Three of the new data elements for which we did not propose
confidentiality determinations in the proposed rule are identical to
other data elements that were included in the analysis at proposal. The
centrifugal compressor name or ID (40 CFR 98.236(o)(2)(i)(A)), the
centrifugal compressor source (40 CFR 98.236(o)(2)(i)(B)), and the
unique name or ID for the leak or vent (40 CFR 98.236(o)(2)(i)(C)) are
identical to the corresponding data elements for reciprocating
compressors in 40 CFR 98.236(p)(2)(i)(A), (p)(2)(i)(B), and
(p)(2)(i)(C). These data elements for reciprocating compressors were
assigned to the ``Facility and Unit Identifier Information'' data
category, and the final confidentiality determination for these data
elements is ``not CBI.'' We conclude that it is appropriate to assign
the three previously omitted data elements to the ``Facility and Unit
Identifier Information'' data category and finalize our determination
that these data elements are ``not CBI'' in this action.
    As discussed in Section II.B.5 of this preamble, the final rule
clarifies the reporting requirements for the time variable used in
Equation W-10A (40 CFR 98.236(g)(5)(i)). Specifically, the final rule
requires reporting of both cumulative gas flowback time values used in
the revised Equation W-10A (``Tp,i'' and
``Tp,s''), whereas the proposed rule inadvertently retained
the current reporting of the single value that is used in Equation W-
10A from the subpart W 2010 final rule. At proposal, the data element
was determined to be an input. However, it is an input only when one
completion or workover has been conducted in a particular sub-basin and
well type combination category. When data for completions or workovers
for multiple wells are included in the calculation, it is a data
element for which a confidentiality determination is required. The
final data elements in 40 CFR 98.236(g)(5)(i) are similar to the data
element in 40 CFR 98.236(h)(2)(iii) for reporting the total number of
hours of venting during completions without hydraulic fracturing. We
assigned the data element in 40 CFR 98.236(h)(2)(iii) to the ``Unit/
Process Operating Characteristics That are Not Inputs to Emission
Equations'' data category and proposed a confidentiality determination
of ``not CBI'' because the cumulative venting time for multiple
completions or workovers would not disclose information on individual
wells and is not likely to cause substantial competitive harm. For the
same reasons, we conclude that it is appropriate to assign the data
elements in 40 CFR 98.236(g)(5)(i), in the cases where they are not
inputs to equations (i.e., when data for more than one well are used in
Equation W-10A), to the ``Unit/Process Operating Characteristics That
are Not Inputs to Emission Equations'' data category and finalize our
determination that these data elements are ``not CBI'' in this action.
In the situations where these data elements are used as an input to an
equation, we are assigning them to the ``Inputs to Emission Equations''
data category and not making a confidentiality determination for these
data.
    In the final rule, the EPA has also edited for clarity numerous
reporting elements based on public comments. Portions of 40 CFR 98.236
also were rearranged to improve clarity in the final rule. These edits
did not change the type of data to be reported and, thus, the
confidentiality determinations do not need to be reassessed. All of the
changes are documented in the Memorandum ``Final Revisions to the
Subpart W Reporting Requirements in the `Greenhouse Gas Reporting Rule:

2014 Revisions and Confidentiality Determinations for Petroleum and
Natural Gas Systems; Final Rule' '' in Docket Id. No. EPA-HQ-OAR-2011-
0512.

B. Summary of Comments and Responses

    This section summarizes the major comments and responses related to
the proposed categorical assignments and confidentiality
determinations. See the 2014 response to comment document in Docket Id.
No. EPA-HQ-OAR-2011-0512 for a complete listing of all comments and
responses. See the memorandum ``Final Data Category Assignments and
Confidentiality Determinations for Data Elements (excluding inputs to
emission equations) in the `Greenhouse Gas Reporting Rule: 2014
Revisions and Confidentiality Determinations for Petroleum and Natural
Gas Systems; Final Rule' '' in Docket Id. No. EPA-HQ-OAR-2011-0512 for
a complete listing of final data category assignments and
confidentiality determinations, and a discussion of changes since
proposal.
    Comment: Two commenters disagreed with the EPA's statement that the
natural gas transmission industry is ``inherently uncompetitive'' or
``less competitive than other industries.'' One commenter pointed out
that although interstate natural gas pipeline rates are established on
a cost-of-service basis by FERC, the FERC-issued Order 636 has fostered
a competitive culture by unbundling pipeline merchant and
transportation services. The commenter argued that pipelines face
multiple forms of competition which affect service offerings and
prices, including: Competition with alternative fuels, competition
between gas supply basins, and competition among pipelines. The
commenter argued that pipelines sometimes charge customers less than
the FERC-approved maximum tariff rate due to competitive market
conditions. Another commenter stated that they operate in markets in
which other natural gas pipeline companies regularly compete for
pipeline business through discounting and other competitive market
practices. Both commenters stated that the release of specific
operational data could result in substantial harm to a pipeline
operator's competitive position.
    Response: The EPA agrees with commenters that Order 636 did
increase competition. We note, however, that many of the data elements
are already publicly available from other sources. The number of
compressors (reported under 40 CFR 98.236(aa)(4)(ii)) and the total
compressor power rating (reported under 40 CFR 98.236(aa)(4)(iii)) are
also available to the public through state and federal construction and
operating permits and FERC. The quantity of gas injected into
underground storage (reported under 40 CFR 98.236(aa)(5)(i)), the
quantity of gas withdrawn from underground storage (reported under 40
CFR 98.236(aa)(5)(ii)), the quantity of LNG injected into storage
(reported under 40 CFR 98.236(aa)(8)(ii)), the quantity of LNG
withdrawn from storage (reported under 40 CFR 98.236(aa)(8)(ii), the
total underground storage capacity (reported under 40 CFR
98.236(aa)(5)(iii)) and the total LNG storage capacity (reported under
40 CFR 98.236(aa)(8)(iii)) are reported annually to the EIA on forms
EIA-176 (Annual Report of Natural and Supplemental Gas Supply) and EIA-
191 (Monthly Underground Gas Storage Report). The EIA publishes this
data on their Web site.\2\ Since these data elements are already in the
public domain, they are not entitled to confidential treatment under 40
CFR 2.208. We are therefore finalizing as proposed the determination
that these data elements are ``not CBI.''
---------------------------------------------------------------------------

    \2\ See the EIA Natural Gas Annual Respondent Query System at
http://www.eia.gov/cfapps/ngqs/ngqs.cfm?f_report=RP7.
---------------------------------------------------------------------------

    We have not identified any reliable public sources for the
following data elements: The quantity of gas transported through a
compressor station (reported under 40 CFR 98.236(aa)(4)(i)) and the
average upstream and downstream pressures (reported under 40 CFR
98.236(aa)(4)(iv) and (v), respectively). These data elements provide
information on the quantity of gas transported by a specific pipeline
and disclosure of this data may potentially cause competitive harm to
some pipeline companies operating in more competitive market areas.
Since the determination would depend on the particular market
conditions for each company, the EPA was not able to make a
determination for these data elements that would apply for all
reporters. Thus, the EPA has decided not to make a confidentiality
determination for 40 CFR 98.236(aa)(4)(i), (iv) and (v). The
confidentiality status of these data elements will be evaluated on a
case-by-case basis, in accordance with the existing CBI regulations in
40 CFR part 2, subpart B, upon receipt of a public request for these
data elements.
    Comment: One commenter supported classifying as CBI, information in
40 CFR 98.236(d)(1)(iv) on whether any CO2 emissions from
the AGR unit are recovered and transferred outside the facility. The
commenter stated that the data element is directly linked to multiple
data elements associated with industrial CO2 production
plants and import/exporter of CO2 that have been previously
determined to be CBI under subpart PP (Suppliers of Carbon Dioxide).
    Response: The EPA has reviewed the data element referenced by the
commenter. The EPA notes that 40 CFR 98.236(d)(1)(iv) includes two data
elements. First, reporters must indicate whether CO2
emissions are recovered from the AGR units and transferred offsite (as
proposed). Second, reporters must supply the quantity of CO2
emissions that are collected and transferred offsite. The second data
element in the proposed rule inadvertently removed text stating that
reporters should report this information under subpart PP. It would be
redundant to report the quantity of CO2 emissions that are
collected and transferred offsite under both subpart PP and subpart W.
In this final rule, we are providing that if any CO2
emissions from the AGR unit were recovered and transferred outside the
facility, then the facility must report the annual quantity of
CO2 that was recovered and transferred outside the facility
under subpart PP.
    Thus, the proposed rule only included one new data element
(``Whether any CO2 emissions are recovered and transferred
outside the facility'') for which a confidentiality determination was
proposed. The EPA has determined that the data element is not the same
data element as reported under subpart PP. Therefore, we are finalizing
as proposed our determination that the data element is ``not CBI.'' The
EPA disagrees with the commenters' assertion that the proposed
determination for ``whether CO2 emissions are recovered from
the AGR units and transferred offsite'' is inconsistent with the
determination made for data elements reported under subpart PP. None of
the data elements reported under subpart PP are similar to this data
element. The determinations for subpart PP were made with regard to
quantities of CO2 from production wells and to the
quantities of CO2 collected and transferred offsite from
industrial production facilities. Furthermore, this data element
reveals only that the facility has an AGR unit (currently publicly
available in permits) and that CO2 is collected as a
byproduct and transferred offsite. Since the CO2 is only a
by-product of the process, the EPA has determined that disclosure of
this information would not cause substantial competitive harm.
    Comment: Five commenters requested that the EPA review
confidentiality

determinations for consistency with data elements that are found in
both subpart NN and subpart W. Several of these commenters provided
citations in subpart NN for data elements that have been given a
determination of CBI which also appear in 40 CFR 98.236(aa)(3)(i)
through 40 CFR 98.236(aa)(3)(vii) in the proposed rule with a ``non-
CBI'' determination.
    Response: The EPA has reviewed the confidentiality determinations
for subparts W and NN and has determined that two data elements in
subpart NN have confidentiality determinations that are inconsistent
with those proposed for subpart W. The first is the quantity of natural
gas withdrawn from storage in a calendar year (reported under 40 CFR
98.236(aa)(5)(i)), which was proposed to be ``not CBI'' for all
underground storage operators. Under subpart NN, local distribution
companies report the volume of natural gas withdrawn from on-system
storage and the annual volume of LNG withdrawn from storage and
vaporized for delivery on the distribution system (40 CFR
98.406(b)(3)), for which we previously made a determination of CBI.
However, review of publicly available data undertaken during the
preparation of the proposal for this action found that gas withdrawals
from underground storage are reported to the EIA on form EIA-176
(Annual Report of Natural And Supplemental Gas Supply and Disposition).
As we noted in the proposal, the EIA considers all information
submitted on EIA-176 to be non-proprietary information and publishes
the quantity of natural gas withdrawn from storage on their Web site.
Since the quantity of natural gas withdrawn from storage is publicly
available, this data element is not entitled to confidential treatment
under the provisions in 40 CFR 2.208. The EPA notes that this final
rule relates to calculation and reporting requirements for subpart W
and not subpart NN, and therefore inconsistencies with respect to
subpart NN are not addressed by this rule.
    The second data element is the quantity of gas received at a gas
processing plant (reported by natural gas processing plants under 40
CFR 98.236(aa)(3)(i)), which we proposed as ``not CBI.'' Plants that
fractionate natural gas into its constituent NGL are required to report
the volume of natural gas received by their plant for processing (see
40 CFR 40 CFR 98.406(a)(3)). In a previous notice, we determined that
the data element required by 40 CFR 98.406(a)(3) was entitled to
confidential treatment under 40 CFR 2.208 because it provided
information regarding raw material consumption that we believed was not
already in the public domain and could potentially cause competitive
harm if disclosed. During the preparation of the proposal for this
action, the EPA found that detailed plant-level information is reported
by all natural gas plants to the EIA on Schedule A of form EIA-757
(Natural Gas Processing Plant Survey) once every 3 years. The
information reported includes the annual average natural gas flow in
million cubic feet per day entering a natural gas plant (including
plants that also fractionate natural gas). EIA considers the
information on annual average natural gas flows entering a plant to be
non-proprietary information that it makes available to the public.
However, because the information reported to EIA is on a different
frequency than that required under subpart W, we have determined that
the quantity of natural gas received at a gas processing plant under 40
CFR 98.236(aa)(3)(i) is entitled to confidential treatment under the
provisions of 40 CFR 2.208. These data provide detailed information
regarding the quantities of natural gas processed that would be likely
to cause competitive harm if disclosed as it provides sensitive
information on market share. Thus, in this final action we are changing
the determination for 40 CFR 98.236(aa)(3)(i) from ``not CBI'' to
``CBI.''
    The other data elements specifically mentioned by commenters are
either not the same as those reported under subpart NN or they have
determinations that are consistent with those in subpart NN. For
example, commenters noted that the quantity of NGL (bulk and
fractionated) received (reported under 40 CFR 98.236(aa)(3)(iii) and
the quantity of NGL (bulk and fractionated) leaving the plant (reported
under 40 CFR 98.236(aa)(3)(iv)) are the same as the data elements
reported under 40 CFR 98.406(a)(2) and (a)(1), respectively. However,
the commenters are mistaken. Under subpart W, the data elements
reported are actually aggregated totals for all NGL products received
and all NGL products supplied. Under subpart NN, facilities report the
quantities of each individual product. The subpart NN data elements
were previously determined to be entitled to confidential treatment
because they provide detailed information regarding the quantities of
individual products that would be likely to cause competitive harm if
disclosed as it provides sensitive information on market share. Since
the NGL data reported under subpart W is in an aggregated form, the
quantities of individual products is not disclosed and therefore does
not pose the same risk of causing competitive harm to the reporters.
The only exception is in situations where the plant is known to receive
or supply only one NGL product. In these situations, the EPA has
decided not to make a confidentiality determination for 40 CFR
98.236(aa)(3)(iii) and (aa)(3)(iv).
    Comment: One commenter expressed concern about reporting
information on exploratory wells in subpart W, especially when the
wells are located in step-out areas where no prior reporting exists for
a given sub-basin (including vertical or horizontal wells). The
commenter explained that the problem occurs when an exploratory well is
the sole well in a sub-basin (including vertical or horizontal wells)
and is not reported in combination with other wells, thereby shielding
any individual well's contribution. The commenter noted that its
concerns are related to the timing of releasing the information to the
public, as the commenter stated that the information is most sensitive
if it is made available too early during the exploration or initial
development stages. The commenter stated that the success of a well in
exploratory areas could be inferred if detailed data are provided to
the public too soon during the exploration and assessment period. The
commenter provided an example of such an occurrence: An exploratory
well completed in December of the reporting year, data reported to the
EPA by end of March of the following year and then released by the EPA
to the public within a few months during the same year. The commenter
stated that early release of data regarding operating characteristics
of such wells, including post-flowback flaring/venting volumes, could
cause competitive harm if made publicly available too early.
    The commenter noted that Federal law and State codes allow
companies to designate as confidential the data obtained from
exploratory wells, especially in new discovery areas or areas that are
being explored for development. The commenter further noted that the
original intent of State oil and gas commissions to allow withholding
of select drilling and production information from early release to the
public was to allow competitive exploration by searching for new
pockets of oil or gas and experimenting with new tools and techniques.
The commenter stated that releasing data on such wells through Part
98--despite the fact that they are held confidential by other
regulatory bodies--could cause substantial

competitive harm and lead to a loss of investment value. The commenter
explained that competitive harm could occur if the public could obtain
detailed high-resolution operational information on a well-by-well
basis and on a daily or weekly basis.
    The commenter requested that the EPA categorically determine that
all information associated with exploratory wells, with the exception
of well ID and location, be classified as CBI for a period of at least
24 months from the start of exploration. The commenter recommended
either of two suggested approaches under Part 98: (1) Companies would
report all data to the EPA as mandated by subpart W, but the EPA would
hold the reported data as CBI and not include it in its public data
release for at least 24 months (this could be accomplished by a
flagging system (or a ``radio button'') in the Electronic Greenhouse
Gas Reporting Tool that could also allow for a short informative text
on why that particular well information is to be maintained
confidential); or (2) the EPA could set up a deferral system where
initial data on exploratory wells will be well ID and location
information and the remaining data would be backfilled by companies
after a period of 24 months. The commenter added that neither option
would require case-by-case review of companies' information, and both
are consistent with the approach taken by state oil and gas commissions
and are protective of companies' commercial investment interests. The
commenter identified the following data elements as potentially
sensitive when reported for exploratory wells:
     Sub-basin ID. (40 CFR 98.236(g)(1))
     Well type. (40 CFR 98.236(g)(2))
     Cumulative backflow time, in hours, for each sub basin.
(40 CFR 98.236(g)(5)(i))
     Vented natural gas volume, in standard cubic feet, for
each well in the sub-basin. (40 CFR 98.236(g)(6))
     Annual gas emissions, in standard cubic feet. (40 CFR
98.236(g)(7))
     For each sub-basin with gas well completions without
hydraulic fracturing and without flaring, Sub-basin ID. (40 CFR
98.236(h)(1)(i))
     For each sub-basin with gas well completions without
hydraulic fracturing and without flaring, average daily gas production
rate for all completions without hydraulic fracturing in the sub-basin
without flaring, in standard cubic feet per hour. (40 CFR
98.236(h)(1)(iv))
     For each sub-basin with gas well completions without
hydraulic fracturing and with flaring, Sub-basin ID. (40 CFR
98.236(h)(2)(i))
     For each sub-basin with gas well completions without
hydraulic fracturing and with flaring, average daily gas production
rate for all completions without hydraulic fracturing in the sub-basin
with flaring, in standard cubic feet per hour. (40 CFR
98.236(h)(2)(iv))
     At the basin level for atmospheric tanks where emissions
were calculated using Calculation Method 3, the total annual oil
throughput that is sent to atmospheric tanks in the basin, in barrels.
(40 CFR 98.236(j)(2)(i)(A))
     If oil well testing is performed where emissions are not
vented to a flare, the average flow rate in barrels of oil per day for
well(s) tested. (40 CFR 98.236(l)(1)(iv))
     If oil well testing is performed where emissions are
vented to a flare, the average flow rate in barrels of oil per day for
well(s) tested. (40 CFR 98.236(l)(2)(iv))
     If gas well testing is performed where emissions are not
vented to a flare, the average annual production rate in actual cubic
feet per day for well(s) tested. (40 CFR 98.236(l)(3)(iii))
     If gas well testing is performed where emissions are
vented to a flare, the average annual production rate in actual cubic
feet per day for well(s) tested. (40 CFR 98.236(l)(4)(iii))
     If associated gas was vented or flared during the calendar
year, Sub-basin ID. (40 CFR 98.236(m)(1))
     For each sub-basin, indicate whether any associated gas
was vented without flaring. (40 CFR 98.236(m)(2))
     For each sub-basin, indicate whether any associated gas
was flared. (40 CFR 98.236(m)(3))
     Volume of oil produced, in barrels, in the calendar year
during the time periods in which associated gas was vented or flared.
(40 CFR 98.236(m)(5))
     Total volume of associated gas sent to sales, in standard
cubic feet, in the calendar year during time periods in which
associated gas was vented or flared. (40 CFR 98.236(m)(6))
     Formation type. (40 CFR 98.236(aa)(1)(ii)(C))
     For each sub-basin category, the number of producing wells
at the end of the calendar year. (40 CFR 98.236(aa)(1)(ii)(D))
     For each sub-basin category, the number of wells completed
during the calendar year. (40 CFR 98.236(aa)(1)(ii)(G))
     For offshore production, the quantity of gas produced from
the offshore platform in the calendar year for sales. (40 CFR
98.236(aa)(2)(i))
    Response: The EPA reviewed the data elements identified by the
commenter as having disclosure concerns for exploratory wells
(delineation wells and wildcat wells). After further investigation in
response to the comment received, review of state laws protecting these
types of data, and consistent with the EPA's previous decisions related
to exploratory wells under Part 98 (79 FR 63750, October 24, 2014), the
EPA has determined that, in the following situations which were not
specifically considered in the proposed rule, early public disclosure
of some of the data elements associated with wildcat wells and/or
delineation wells could reveal the well productivity, thereby resulting
in the loss of investment value:
     For gas well completions or workovers with hydraulic
fracturing, where wildcat wells and/or delineation wells are the only
wells in a sub-basin that can be used for the measurement;
     For gas well completions without hydraulic fracturing,
where wildcat wells and/or delineation wells are the only wells in a
sub-basin that can be used for the measurement;
     For onshore production storage tanks, where wildcat wells
and/or delineation wells are the only wells in a sub-basin or basin;
     For well testing, where wildcat wells and/or delineation
wells are the only wells in a sub-basin that are tested;
     For associated gas venting and flaring, where wildcat
wells and/or delineation wells are the only wells in a sub-basin;
    The data elements that could reveal well productivity for wildcat
and/or delineation wells in the applicable situations listed above are
as follows:
     Cumulative flowback time, in hours, for each sub basin.
(40 CFR 98.236(g)(5)(i))
     For the measured well(s), the flowback rate, in standard
cubic feet per hour, for each sub-basin. (40 CFR 98.236(g)(5)(ii))
     For each sub-basin with gas well completions without
hydraulic fracturing and without flaring, average daily gas production
rate for all completions without hydraulic fracturing in the sub-basin
without flaring, in standard cubic feet per hour. (40 CFR
98.236(h)(1)(iv))
     For each sub-basin with gas well completions without
hydraulic fracturing and with flaring, average daily gas production
rate for all completions without hydraulic fracturing in the sub-basin
with flaring, in standard cubic feet per hour. (40 CFR
98.236(h)(2)(iv))
     At the sub-basin level for atmospheric tanks where
emissions were calculated using Calculation Method 1 or 2, the total
annual gas-

liquid separator oil volume that is sent to atmospheric storage tanks,
in barrels. (40 CFR 98.236(j)(1)(iii))
     At the basin level for atmospheric tanks where emissions
were calculated using Calculation Method 3, the total annual oil
throughput that is sent to atmospheric tanks in the basin, in barrels.
(40 CFR 98.236(j)(2)(i)(A))
     If oil well testing is performed where emissions are not
vented to a flare, the average flow rate in barrels of oil per day for
well(s) tested. (40 CFR 98.236(l)(1)(iv))
     If oil well testing is performed where emissions are
vented to a flare, the average flow rate in barrels of oil per day for
well(s) tested. (40 CFR 98.236(l)(2)(iv))
     If gas well testing is performed where emissions are not
vented to a flare, the average annual production rate in actual cubic
feet per day for well(s) tested. (40 CFR 98.236(l)(3)(iii))
     If gas well testing is performed where emissions are
vented to a flare, the average annual production rate in actual cubic
feet per day for well(s) tested. (40 CFR 98.236(l)(4)(iii))
     Volume of oil produced, in barrels, in the calendar year
during the time periods in which associated gas was vented or flared.
(40 CFR 98.236(m)(5))
     Total volume of associated gas sent to sales, in standard
cubic feet, in the calendar year during time periods in which
associated gas was vented or flared. (40 CFR 98.236(m)(6))
    These 12 data elements are themselves a very small subset of data
elements collected in subpart W. Further, wildcat and delineation wells
represent a relatively small percentage of the wells being reported
under Part 98 for these data elements. As a result, in the interim
period before these data are reported to the EPA, the EPA will be able
to verify the majority of the emissions using data elements that will
be reported to the EPA. For the 12 data elements that may be delayed
for 2 years, the EPA will verify emissions using other data reported to
the EPA, and will conclude verification upon receipt of the data. The
EPA agrees with the commenter that a two year delay of reporting is
sufficient to prevent early public disclosure of these data and will
provide sufficient time for the reporter to thoroughly conduct an
assessment of the well. Given the results of this evaluation, the EPA
determined that, for these 12 data elements, in those cases where a
reporter has delineation wells or wildcat wells in cases where wildcat
wells and/or delineation wells in a sub-basin and these wells meet one
of the five situations described above, reporters should be provided an
option to delay reporting of the given data element for two reporting
years starting in 2015. In such cases, if the two-year delay in
reporting is used, the reporter must report the following information
in the current reporting year: indicate for each delayed reporting
element that one of the five situations listed above is true (e.g., for
gas well completions or workovers with hydraulic fracturing, wildcat
wells and/or delineation wells are the only wells in a sub-basin that
can be used for the measurement). In addition, when reporters report
the delayed data elements to emission equations after the 2 year delay,
they must also report the American Petroleum Institute (API) well ID
numbers for the applicable wildcat and/or delineation wells in the sub-
basin for which the reporting element was delayed. For example, if a
delineation or wildcat well is completed in 2015 in a sub-basin that
has only delineation or wildcat wells or these are the only wells for
which measurements can be made, then the reporter may (1) elect to
report these 12 data elements in their 2015 annual report submitted by
March 31, 2016; or (2) elect to delay reporting of these data elements
for up to two years. If the reporter elects to delay reporting, then
the API well ID numbers for the wildcat and delineation wells in the
sub-basin for which reporting has been delayed must be reported by
March 31, 2016 and the data elements delayed from reporting must be
reported no later than March 31, 2018.
    The following data elements meet the definition of emission data in
40 CFR 2.301(a)(2)(i) because they are actual volumes of gas emitted by
the facility: volume of natural gas vented (reported under 40 CFR
98.236(g)(6)) and annual gas emissions (reported under 40 CFR
98.236(g)(7)). Under CAA section 114(c), the EPA must make available
emission data, whether or not such data are CBI. For these data
elements that are assigned to the ``Emissions'' data category, the
commenter did not claim or provide any justification for why these data
elements do not meet the definition of emission data.
    For the remaining data elements identified by the commenter as
potentially sensitive with respect to delineation and wildcat wells,
the EPA disagrees that public disclosure of these data elements in the
time period following annual reporting would reveal well productivity,
thereby resulting in the loss of investment value to the reporter. The
sub-basin ID (reported under 40 CFR 98.236(g)(1), (h)(1)(i), (h)(2)(i),
and (m)(1)) and number of wells can be discerned from the well IDs,
which are publicly available for all wells and provide the location of
the well and the name of the drilling company. Since the location of
the well can be discerned from the well ID, the type of formation
(reported under 40 CFR 98.236(aa)(1)(ii)(C)) can be determined through
publicly available information such as U.S. Geological Survey reports.
The well type (reported under 40 CFR 98.236(g)(2)), including whether
hydraulic fracturing is used, can be inferred from the formation type.
Similarly, although indicating whether the well vents or flares
associated gas emissions (reported under 40 CFR 98.236(m)(2) and
(m)(3)) identifies the well as an oil well, this information can also
be concluded from the formation type, which, as previously mentioned,
may be determined through publicly available information. The number of
producing wells at the end of the calendar year (reported under 40 CFR
98.236(aa)(1)(ii)(D)) and the number of wells completed during the
calendar year (reported under 40 CFR 98.236(aa)(1)(ii)(G)) are reported
for sub-basins with production wells. Information regarding production
wells is available from state databases. Since these data elements are
either not sensitive or can be easily inferred from information already
in the public domain, the EPA has determined that release of this
information would not result in competitive harm.

IV. Impacts of the Final Amendments to Subpart W

A. Impacts of the Final Amendments

    The final amendments to subpart W include technical corrections and
revisions to the calculation, monitoring, and reporting requirements
that do not significantly increase the burden of data collection and
improve the accuracy of the data reported. In general, these revisions
provide greater flexibility for reporters and increase the clarity and
congruency of the calculation and reporting requirements. These final
amendments do not impart significant additional burden to reporters and
in some cases reduce burden to reporters and regulators.
    First, the following revisions to the calculation and monitoring
requirements of subpart W are anticipated to decrease the burden or
have no impact on the burden relative to the burden to comply with the
current rule:
     Allowing for the use of either site-specific composition
data or a default gas composition for natural gas transmission
compression, underground natural gas storage, LNG storage, LNG

import and export, and natural gas distribution facilities.
     For well venting from liquids unloading, allowing the
measurement period to differ slightly from the standard calendar year
combined with annualizing the resulting venting data for facilities
that calculate emissions using a recording flow meter.
     Allowing for the option to use a site-specific
compressibility factor for calculation of emissions from blowdown vents
and for conversion of volumetric emissions at actual conditions to
standard conditions.
     Revising calculation methods for onshore production
storage tanks to require quantification of emissions from well pad gas-
liquid separator liquid dump valves only if the dump valve is
determined to not be closing properly.
     Including a term to account for situations where part of
the associated gas from a well goes to a sales line while another part
of the gas is flared or vented. The term is already being calculated
elsewhere and/or can be estimated.
     Deciding against finalizing the addition of the term
``EREp,q'' for emissions reported under other sources;
therefore, reporters will not be required to track these emissions.
     Removing vented compressor emissions routed to a flare
from the compressor emissions total and retaining the requirement to
report uncontrolled vented emissions from compressors.
     Addressing reporter concerns related to measuring
centrifugal and reciprocating compressor emissions that are routed to a
common vent manifold or flare header. Reporters were previously
required to conduct emissions measurements for each individual
compressor routed to the common vent. The final rule requires only a
single annual emissions measurement at the common vent for groups of
manifolded compressors. We are not finalizing the proposed requirement
to conduct measurement of manifolded compressor source emissions before
comingling with emissions from other sources.
     Revising requirements to conduct measurements in the not-
operating-depressurized mode once every three years or at the next
scheduled depressurized shutdown (for centrifugal compressors) or at
the next scheduled shutdown when the compressor rod packing is replaced
(for reciprocating compressors). We are not finalizing the proposed
requirement to conduct testing in the operating-mode once every 3
years.
     Revising calculation methods for the natural gas
distribution segment to clarify the calculation methodologies and
reporting requirements for above grade metering-regulating stations.
     Removing the existing best available monitoring method
(BAMM) provisions in 40 CFR 98.234(f) and providing transitional BAMM
for the 2015 calendar year. Removing the existing provisions does not
add to previous burden estimates for subpart W reporters; these
estimates were prepared based on all reporters complying with the
monitoring methods in 40 CFR 98.234 without BAMM. The transitional BAMM
included in this final rule would allow facilities to obtain the
necessary equipment to conduct measurements as required under the
revised calculation methods in this final rule, and would not add to
the burden estimates included in the proposed rule. (See further
discussion in Section II.D of this preamble.)
     Providing for the use of optical gas imaging as a
screening tool to detect emissions from reciprocating and centrifugal
compressors; measurement to quantify the emissions is required only if
the screening detects emissions.
     Providing clarified, specific missing data procedures that
provide guidance for reporters when a measurement is inadvertently
missed.
    Second, the following revisions to the calculation, monitoring, and
reporting requirements of subpart W slightly increase the burden
relative to the burden to comply with the current rule:
     Revising the calculation and reporting requirements for
completions and workovers to differentiate between completions and
workovers with different well type combinations in each sub-basin
category.
     Revising the calculation and reporting requirements for
onshore natural gas transmission compression, underground natural gas
storage, LNG storage, and LNG import and export to include emissions
from flare stacks.
    Finally, the following revisions to the reporting requirements for
subpart W do increase the burden of data collection, but not
significantly. As further discussed in Section II of this preamble, the
EPA is finalizing the addition of 247 new data elements, while
substantially revising 13 data elements and deleting 34 data elements
that were required to be reported under Part 98. Although not
previously required to be reported, many of these data elements are
typically already collected by reporters, related to data that are
already being reported, or are readily available to reporters. For
example, some of the new reporting elements are required for use in
subpart W equations used to calculate emissions and others are
collected to differentiate between identical equipment types.
    These final additions improve the quality of the data reported by
removing ambiguity for the reporter and do not increase burden
significantly, since the reporting elements are already available.
    The EPA received multiple comments regarding the impacts of the
proposed amendments. After evaluating these comments and reviewing
other changes from proposal, the EPA revised the impacts assessment.
The final amendments to subpart W are not expected to significantly
increase burden. See the memorandum, ``Assessment of Impacts of the
2014 Final Revisions to Subpart W'' in Docket Id. No. EPA-HQ-OAR-2011-
0512 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. See the
2014 response to comment document in Docket Id. No. EPA-HQ-OAR-2011-
0512 for a complete listing of all comments and responses.
    Comment: Several commenters stated that the EPA significantly over-
simplified the impacts and underestimated the burden associated with
the proposed rule. Specifically, commenters expressed concern that EPA
has significantly underestimated the additional time and cost burden of
the expanded reporting requirements. One commenter considered the
implementation cost to be underestimated by an order of magnitude or
more, providing an estimate of an additional $150,000 per company or
more to initially identify, collect, document and report the new data
elements with another $100,000 per year. This commenter critiqued the
``Assessment of Impacts of 2014 Proposed Revisions to Subpart W'' and
the information collection request (ICR) Supporting Statement and
stated that many of the time and cost burdens should be much higher
than the numbers included in these documents. The commenter stated that
the cost estimates do not include management tasks including review of
the proposed rule and final revisions, monitoring plan revisions,
internal communications, coordination with technical staff, training,
systems updates, or associated budgeting and planning. One concern was
the assumption that 3 minutes would be required to find, document, and
report each new data element. The

commenter pointed out that the estimate does not consider the level of
effort required to determine who collects the data or how and where it
is documented. Another commenter reported that their company had
invested in a robust system to manage data collection and reporting
according to the original rule requirements, and the revised changes
would be burdensome and costly.
    Response: Although the commenter did not elaborate on the
assumptions used to calculate the $150,000 initial cost or the $100,000
annual cost, the EPA disagrees with the magnitude of these costs.
Overall, the EPA has determined that the cost estimates provided by the
commenters do not take into consideration the completion of one-time
activities that occurred in the first year of data collection. In the
EPA's cost estimates, we assumed the startup costs would be incurred
during the first year of reporting, i.e., the 2011 reporting year.
These costs included the labor burden of planning, registration, and
installing required equipment to comply with the rule, as well as the
initial costs of developing a data tracking system.
    The EPA maintains that allowing 3 minutes per data element is
accurate. All new reporting elements are related to emission sources
for which information is already being gathered and reported under
subpart W. The new elements include such information as the name or ID
of the emission source, measurement dates, installation dates,
maintenance dates, equipment counts, measurement counts, operating
hours, etc. Most, if not all, of these elements can be gathered at the
same time as required measurements are being taken.
    Comment: One commenter stated that the EPA cost analysis
incorrectly assumes an incremental time of 10 minutes for a technician
to conduct each additional compressor source measurement for manifolded
compressors. The commenter stated that this estimate fails to consider
the time required to move personnel and equipment from compressor to
compressor and the cautious pace of work and work practices (e.g., use
of lanyard and/or other fall protection) for safely working at elevated
locations. The commenter also pointed out that the measurement estimate
appears to assume that the technician is working alone, reiterating
that personnel do not work alone at elevated locations. The commenter
further asserted that the EPA's burden estimate for compressor testing
appears to include costs only for the testing contractor and does not
include facility and company costs including scheduling, coordination,
and test team support. The commenter stated that the proposed rule
fails to account for costs associated with three separate measurements.
    Response: The original burden estimate referenced by the commenter
was an adjustment to the burden estimate for the subpart W 2010 final
rule to reflect the proposed changes for manifolded compressors. For
manifolded compressors, the EPA proposed that reporters may measure
downstream of the manifold, in lieu of measuring each compressor source
individually. Therefore, the measurement burden estimates assumed that
the technician would be taking a single measurement at the manifold and
that the level of effort associated with manifolded measurements are
similar to the level of effort associated with measurements for
individual compressors.
    Additionally, in this final rule, we are specifying that ``as
found'' measurements from manifolded compressors be taken one time per
year instead of three separate measurements per year as proposed.

V. 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 not a ``significant regulatory action'' under the
terms of Executive Order 12866 (58 FR 51735, October 4, 1993) and is
therefore not subject to review under Executive Orders 12866 and 13563
(76 FR 3821, January 21, 2011).
    In addition, the EPA prepared an analysis of the potential costs
and benefits associated with the final amendments to subpart W. This
analysis is contained in the memorandum ``Assessment of Impacts of the
2014 Final Revisions to Subpart W.'' A copy of the analysis is
available in the docket for this action (see Docket Id. No. EPA-HQ-OAR-
2011-0512) and the analysis is briefly summarized in Section IV of this
preamble.

B. Paperwork Reduction Act

    The information collection requirements in this final rule have
been submitted for approval to the Office of Management and Budget
(OMB) under the Paperwork Reduction Act, 44 U.S.C. 3501 et seq. The ICR
document prepared by the EPA has been assigned OMB control number 2060-
0629 and EPA ICR tracking number 2300.15.
    This action simplifies the existing reporting methods in subpart W,
clarifies monitoring methods and data reporting requirements, and
finalizes confidentiality determinations for reported data elements.
The EPA is restructuring the reporting requirements for clarity and to
align them with the calculation requirements by adding 247 new data
elements, substantially revising 13 data elements, and deleting 34 data
elements.
    OMB has previously approved the information collection requirements
for 40 CFR part 98 under the provisions of the Paperwork Reduction Act,
44 U.S.C. 3501 et seq., and has assigned OMB control number 2060-0629
and EPA ICR tracking number 2300.12. The OMB control numbers for the
EPA's regulations in 40 CFR are listed in 40 CFR part 9. Burden is
defined at 5 CFR 1320.3(b).
    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.
    The information collection will result in an overall increase in
annual burden of approximately 7,700 hours and $600,000. The estimated
total projected cost and hour burden associated with reporting for
subpart W are approximately $22,024,000 and 244,000 hours,
respectively. For the hour burden, the estimated average burden hours
per response is 53.7 hours, the frequency of response is once annually,
and the estimated number of likely respondents is 2,885. These
amendments to subpart W affect the labor costs, not the capital costs
and operation and maintenance (O&M) costs. Therefore, the estimated
total capital and start-up cost of monitoring equipment and related
facility/process modifications annualized over the expected useful life
of the equipment remains at $796,000 per year, and the total O&M cost
remains at $1,690,000 per year. The total labor cost is $19,538,000 per
year for all of subpart W.

C. Regulatory Flexibility Act (RFA)

    The Regulatory Flexibility Act (RFA) generally requires an agency
to prepare a regulatory flexibility analysis of any rule subject to
notice and comment rulemaking requirements under the Administrative
Procedure Act or any other statute unless the agency certifies that the
rule will not have a significant economic impact on a substantial
number of small entities. Small entities include small businesses,
small organizations, and small governmental jurisdictions.

    For purposes of assessing the impacts of today's final rule on
small entities, small entity is defined as: (1) A small business as
defined by the Small Business Administration's regulations at 13 CFR
121.201; (2) a small governmental jurisdiction that is a government of
a city, county, town, school district or special district with a
population of less than 50,000; and (3) a small organization that is
any not-for-profit enterprise which is independently owned and operated
and is not dominant in its field.
    This action (1) amends monitoring and calculation methodologies in
subpart W; (2) amends reporting requirements; (3) assigns subpart W
data reporting elements into CBI data categories; and (4) amends a
definition in subpart A. After considering the economic impacts of
these final rule amendments on small entities, I certify that this
action will not have a significant economic impact on a substantial
number of small entities. The small entities directly regulated by this
final rule include small businesses in the petroleum and gas industry,
small governmental jurisdictions and small non-profits. The EPA has
determined that some small businesses would be affected because their
production processes emit GHGs exceeding the reporting threshold.
    This action includes final amendments that do not result in a
significant burden increase on subpart W reporters. In some cases, the
EPA is increasing flexibility in the selection of methods used for
calculating GHGs, and is also revising certain methods that may result
in greater conformance to current industry practices. In addition, the
EPA is revising specific provisions to provide clarity on what
information is being reported. These revisions would not significantly
increase the burden on reporters while maintaining the data quality of
the information being reported to the EPA.
    Although this final rule will not have a significant economic
impact on a substantial number of small entities, the EPA nonetheless
has tried to reduce the impact of this rule on small entities. As part
of the process of finalizing the subpart W 2010 final rule, the EPA
took several steps to evaluate the effect of the rule on small
entities. For example, the EPA determined appropriate thresholds that
reduced the number of small businesses reporting. In addition, the EPA
supports a ``help desk'' for the rule, which is available to answer
questions on the provisions in the rule. Finally, the EPA continues to
conduct significant outreach on the GHG reporting rule and maintains an
``open door'' policy for stakeholders to help inform the EPA's
understanding of key issues for the industries.

D. Unfunded Mandates Reform Act (UMRA)

    This rule contains no federal mandate that may result in
expenditures of $100 million or more for state, local, and tribal
governments, in the aggregate, or the private sector in any one year.
Thus, this rule is not subject to the requirements of section 202 and
205 of the UMRA. This rule is also not subject to the requirements of
section 203 of UMRA because it contains no regulatory requirements that
might significantly or uniquely affect small governments. This action
(1) amends monitoring and calculation methodologies in subpart W; (2)
amends reporting requirements, (3) assigns subpart W data reporting
elements into CBI data categories; and (4) amends a definition in
subpart A. The rule applies to few, if any, small governments.
Therefore, this action is not subject to the requirements of section
203 of the UMRA.

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, as
specified in Executive Order 13132. However, for a more detailed
discussion about how Part 98 relates to existing state programs, please
see Section II of the preamble to the final Part 98 rule (74 FR 56266,
October 30, 2009).
    Few, if any, state or local government facilities would be affected
by the provisions in this rule. This regulation also does not limit the
power of States or localities to collect GHG data and/or regulate GHG
emissions. Thus, Executive Order 13132 does not apply to this action.

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

    Subject to the Executive Order 13175 (65 FR 67249, November 9,
2000) the EPA may not issue a regulation that has tribal implications,
that imposes substantial direct compliance costs, and that is not
required by statute, unless the federal government provides the funds
necessary to pay the direct compliance costs incurred by tribal
governments, or the EPA consults with tribal officials early in the
process of developing the proposed regulation and develops a tribal
summary impact statement.
    The EPA has concluded that this action may have tribal
implications. However, it will neither impose substantial new direct
compliance costs on tribal governments, nor preempt Tribal law. This
regulation would apply directly to petroleum and natural gas facilities
that emit GHGs. Although few facilities that would be subject to the
rule are likely to be owned by tribal governments, the EPA has 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 early in the process of developing
subpart W to permit them to have meaningful and timely input into its
development.
    For additional information about the EPA's interactions with tribal
governments, see 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 (62 FR 19885, April 23,
1997) as applying only to those regulatory actions that concern health
or safety risks, such that the analysis required under section 5-501 of
the Executive Order has the potential to influence the regulation. This
action is not subject to Executive Order 13045 because it does not
establish an environmental standard intended to mitigate health or
safety risks.

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

    This action is not subject to Executive Order 13211 (66 FR 28355
(May 22, 2001)), because it is not a significant regulatory action
under Executive Order 12866.

I. National Technology Transfer and Advancement Act

    Section 12(d) of the National Technology Transfer and Advancement
Act of 1995 (NTTAA), Public Law 104-113 (15 U.S.C. 272 note) directs
the EPA to use voluntary consensus standards in its regulatory
activities unless to do so would be inconsistent with applicable law or
otherwise impractical. Voluntary consensus standards are technical

standards (e.g., materials specifications, test methods, sampling
procedures, and business practices) that are developed or adopted by
voluntary consensus standards bodies. NTTAA directs EPA to provide
Congress, through OMB, explanations when the Agency decides not to use
available and applicable voluntary consensus standards. This action
does not involve the use of any new technical standards. No changes are
being finalized that affect the test methods currently in use for
subpart W. Although the EPA is revising this final rule to allow for
the use of additional measurement methods (optical gas imaging
instrument) for pre-screening of compressor valve leakage, these
revisions rely on existing technical standards in subpart W for similar
emission sources. Therefore, the EPA is not considering the use of any
new voluntary consensus standards.

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

    Executive Order 12898 (59 FR 7629, (February 16, 1994)) establishes
federal executive policy on environmental justice. Its main provision
directs federal agencies, to the greatest extent practicable and
permitted by law, to make environmental justice part of their mission
by identifying and addressing, as appropriate, disproportionately high
and adverse human health or environmental effects of their programs,
policies, and activities on minority populations and low-income
populations in the United States.
    The EPA has determined that this rule will not have
disproportionately high and adverse human health or environmental
effects on minority or low-income populations because it does not
affect the level of protection provided to human health or the
environment. Instead, this rule addresses information collection and
reporting procedures.

K. Congressional Review Act

    The Congressional Review Act, 5 U.S.C. 801 et seq., as added by the
Small Business Regulatory Enforcement Fairness Act of 1996, generally
provides that before a rule may take effect, the agency promulgating
the rule must submit a rule report, which includes a copy of the rule,
to each House of the Congress and to the Comptroller General of the
United States. The EPA will submit a report containing this rule and
other required information to the U.S. Senate, the U.S. House of
Representatives, and the Comptroller General of the United States prior
to publication of the rule in the Federal Register. A major rule cannot
take effect until 60 days after it is published in the Federal
Register. This action is not a ``major rule'' as defined by 5 U.S.C.
804(2). This rule will be effective on January 1, 2015.

List of Subjects in 40 CFR Part 98

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

    Dated: November 13, 2014.
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 A--GENERAL PROVISIONS

0
2. Section 98.6 is amended by revising the definition of ``Well
completions'' to read as follows:

Sec.  98.6  Definitions.

* * * * *
    Well completions means the process that allows for the flow of
petroleum or natural gas from newly drilled wells to expel drilling and
reservoir fluids and test the reservoir flow characteristics, steps
which may vent produced gas to the atmosphere via an open pit or tank.
Well completion also involves connecting the well bore to the
reservoir, which may include treating the formation or installing
tubing, packer(s), or lifting equipment, steps that do not
significantly vent natural gas to the atmosphere. This process may also
include high-rate flowback of injected gas, water, oil, and proppant
used to fracture and prop open new fractures in existing lower
permeability gas reservoirs, steps that may vent large quantities of
produced gas to the atmosphere.
* * * * *

Subpart W--PETROLEUM AND NATURAL GAS SYSTEMS

0
3. Section 98.230 is amended by revising paragraph (a)(2) 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.
* * * * *

0
4. Section 98.232 is amended by:
0
a. Revising paragraphs (c)(11), (d)(1), and (e)(1);
0
b. Adding paragraph (e)(6);
0
c. Revising paragraph (f)(1) and adding paragraph (f)(4);
0
d. Revising paragraph (g)(1) and adding paragraph (g)(4);
0
e. Revising paragraph (h)(1) and adding paragraph (h)(5); and
0
f. Revising paragraphs (i)(1) through (i)(7).
    The revisions and additions read as follows:

Sec.  98.232  GHGs to report.

* * * * *
    (c) * * *
    (11) Reciprocating compressor venting.
* * * * *
    (d) * * *
    (1) Reciprocating compressor venting.
* * * * *
    (e) * * *
    (1) Reciprocating compressor venting.
* * * * *
    (6) Flare stack emissions.
    (f) * * *
    (1) Reciprocating compressor venting.
* * * * *
    (4) Flare stack emissions.
* * * * *
    (g) * * *
    (1) Reciprocating compressor venting.
* * * * *
    (4) Flare stack emissions.
    (h) ** * *
    (1) Reciprocating compressor venting.
* * * * *

    (5) Flare stack emissions.
    (i) * * *
    (1) Equipment leaks from connectors, block valves, control valves,
pressure relief valves, orifice meters, regulators, and open-ended
lines at above grade transmission-distribution transfer stations.
    (2) Equipment leaks at below grade transmission-distribution
transfer stations.
    (3) Equipment leaks at above grade metering-regulating stations
that are not above grade transmission-distribution transfer stations.
    (4) Equipment leaks at below grade metering-regulating stations.
    (5) Distribution main equipment leaks.
    (6) Distribution services equipment leaks.
    (7) Report under subpart W of this part the emissions of
CO2, CH4, and N2O emissions from
stationary fuel combustion sources following the methods in Sec.
98.233(z).
* * * * *

0
5. Section 98.233 is amended by:
0
a. Revising the introductory text;
0
b. Revising paragraphs (a) introductory text, (a)(1), and (a)(2) and
adding paragraph (a)(4);
0
c. Revising paragraphs (c), (d), (e), (f), (g), (h), and (i);
0
d. Revising paragraphs (j) introductory text, (j)(1) introductory text,
(j)(1)(vii) introductory text, and (j)(2);
0
e. Removing paragraphs (j)(3) and (j)(4);
0
f. Redesignating paragraphs (j)(5) through (j)(9) as paragraphs (j)(3)
through (j)(7) and revising newly redesignated paragraphs (j)(3)
through (j)(7);
0
g. Revising paragraphs (k), (l), (m), (n), (o), (p), (q), and (r);
0
h. Revising paragraphs (s)(2) introductory text, (s)(2)(i), (s)(3), and
(s)(4);
0
i. Revising paragraphs (t) introductory text, (t)(1), and (t)(2);
0
j. Revising paragraphs (u) introductory text and (u)(2)(iii) through
(vii);
0
k. Revising paragraphs (v), (w) introductory text, (w)(1), and (w)(3)
introductory text;
0
l. Revising the parameters ``MassCO2,'' ``N,'' and
``Vv'' to Equation W-37 in paragraph (w)(3);
0
m. Revising the introductory text of paragraph (x) and paragraph
(x)(1);
0
n. Revising the parameter ``Shl'' to Equation W-38 in
paragraph (x)(2);
0
o. Revising paragraph (z)(1);
0
p. Revising the parameters ``Va,'' ``YCO2,''
``Yj,'' and ``YCH4'' to Equations W-39A and W-39B
in paragraph (z)(2)(iii);
0
q. Revising Equation W-40 in paragraph (z)(2)(vi) and the parameters
``MassN2O,'' ``Fuel,'' and ``HHV'' to Equation W-40 in
paragraph (z)(2)(vi);
0
r. Removing the parameter ``GWP'' of Equation W-40 in paragraph
(z)(2)(vi).
    The revisions and additions read as follows:

Sec.  98.233  Calculating GHG emissions.

    You must calculate and report the annual GHG emissions as
prescribed in this section. For calculations that specify measurements