------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                Changes Implemented in RY2016
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
I...............................................................              $0              $0          $1,226          \a\ $0              $0              $0          $1,226          \a\ $0
HH..............................................................               0               0           8,132           8,132               0               0           8,132           8,132
                                                                                -----------------------------------------------
    Total Costs for Changes Implemented in RY2016...............  ..............  ..............  ..............  ..............  ..............           9,359           8,132
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                Changes Implemented in RY2017
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
A...............................................................               0               0           4,906           4,906               0               0           4,906           4,906
C...............................................................               0               0          12,139          12,139               0               0          12,139          12,139
E...............................................................               0               0              10              10               0               0              10              10
F...............................................................               0               0              73              73               0               0              73              73
G...............................................................               0               0             228             228               0               0             228             228
N \b\...........................................................               0               0               0               0               0               0               0               0
O...............................................................               0               0             106             106               0               0             106             106
P \b\...........................................................               0               0               0               0               0               0               0               0
Q \b\...........................................................               0               0               0               0               0               0               0               0
S...............................................................               0               0             744             744               0               0             744             744
U \b\...........................................................               0               0               0               0               0               0               0               0
X...............................................................               0               0           1,074           1,074               0               0           1,074           1,074
Z...............................................................               0               0              40              40               0               0              40              40
AA \b\..........................................................               0               0               0               0               0               0               0               0
CC..............................................................               0               0              33              33               0               0              33              33
DD..............................................................               0               0           2,000           2,000               0               0           2,000           2,000
II..............................................................               0               0           2,562           2,562               0               0           2,562           2,562
LL \c\..........................................................               0               0             -17             -17               0               0             -17             -17
MM \b\..........................................................               0               0               0               0               0               0               0               0
NN..............................................................               0               0           1,752           1,752               0               0           1,752           1,752
PP \b\..........................................................               0               0               0               0               0               0               0               0
RR \d\..........................................................               0               0               0               0               0               0               0               0
TT \b\..........................................................               0               0               0               0               0               0               0               0
UU \b\..........................................................               0               0               0               0               0               0               0               0
                                                                                -----------------------------------------------

    Total Costs for Changes Implemented in RY2017...............  ..............  ..............  ..............  ..............  ..............  ..............          25,650          25,650
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                Changes Implemented in RY2018
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
V...............................................................          83,544          66,403             129             129               0               0          83,673          66,531
Y...............................................................               0               0           1,448           1,448               0               0           1,448           1,448
FF..............................................................               0               0           2,066           2,066       1,848,571         949,582       1,850,638         951,648
OO..............................................................          36,215          26,612             582             582               0               0          36,797          27,194
                                                                                -----------------------------------------------
    Total Costs for Changes Implemented in RY2018...............  ..............  ..............  ..............  ..............  ..............  ..............       1,972,555       1,046,821
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
        Total (All Subparts)....................................         119,759          93,015          39,234          38,007       1,848,571         949,582       2,006,337       1,081,830
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
\a\ Costs for subpart I include new data elements related to the triennial technology report required by Sec.   98.96(y). The first report must be submitted with RY2016 reports on March 31,
  2017 and every three years thereafter. For the purposes of estimating burden, the annual costs associated with the data elements were included in the total incremental estimates for RY2016
  and RY2019 (see Table 9 of this preamble) and not for RY2017 or RY2018.
\b\ The proposed changes to this subpart include only minor revisions, clarifications, and corrections that have no impact on the burden to reporters.
\c\ This entry is a negative value because certain reporting requirements were removed from subpart LL and no new reporting requirements were added for the subpart, resulting in a net cost
  savings for this source category.
\d\ There is no increase in costs under subpart RR (Geologic Sequestration of Carbon Dioxide) because there are no facilities currently reporting, or projected to report, under this source
  category in the next three years.

    A full discussion of the impacts may be found in the memorandum,
``Assessment of Burden Impacts of 2015 Revisions to the Greenhouse Gas
Reporting Rule,'' available in Docket Id. No. EPA-HQ-OAR-2015-0526.

A. How was the incremental burden of the proposed rule estimated?

    The estimated incremental change in burden from the proposed
amendments to Part 98 include burden associated with: (1) Changes to
the reporting requirements by adding, revising, or removing existing
reporting requirements (21 subparts); (2) revisions to the
applicability of subparts such that additional facilities would be
required to report under Part 98 (subparts V and OO); and (3)
additional monitoring requirements (subpart FF).
1. Burden Associated With the Revision of Reporting Requirements
    Section III of this preamble describes proposed amendments to each
subpart of Part 98 that improve the quality and accuracy of the data
collected under the GHGRP, improve verification of collected data, and
provide additional data to help improve estimates included in the U.S.
GHG Inventory. In general, these proposed amendments would add
reporting requirements or revise existing reporting requirements to
collect more detailed facility data. The proposed amendments would
collectively add or revise data elements in 21 subparts of Part 98,
including 97 data elements that were not previously required to be
collected. With the exception of revisions to subpart FF (Underground
Coal Mines), the collection of these new and revised data elements
would not add new monitoring requirements, and would not substantially
affect the type of information that must be collected. For all of these
additional data elements, the EPA has estimated a nominal additional
cost to report the data element and fulfill the recordkeeping
requirements. The EPA is also proposing to remove 18 data elements in
subparts O, Y, DD, HH, and LL. For these data elements, the EPA has
estimated a nominal reduction in cost, since reporters would no longer
be required to report the data element. The total incremental costs
from the addition, revision, and removal of these reporting
requirements are anticipated at $39,234 annually ($2011). This includes
$9,359 from revisions implemented in RY2016, $25,650 from revisions
first implemented in RY2017, and $4,225 from revisions first
implemented in RY2018. For subpart I, the new data elements in the
proposed rule pertain to the triennial technology report required under
40 CFR 98.96(y), which must first be submitted with RY2016 reports on
or before March 31, 2017 and every three years thereafter. For the
purposes of estimating burden, the annual costs associated with these
data elements ($1,226) would apply in RY2016 only. For RY2017 and
RY2018, the estimated incremental cost associated with reporting the
new, revised, and removed data elements for all affected source
categories is $33,782 and $38,007, respectively.
    All costs to the regulated industry resulting from changes to the
reporting requirements for the GHGRP are labor costs (i.e., the cost of
labor by facility staff to meet the rule's information collection
requirements). For each subpart, the EPA determined the incremental
change in annual hourly labor estimates by multiplying the number of
data elements that were added, revised, or removed in each subpart by
the number of hours required to review each data element and the number
of affected reporters for each subpart. Where data elements were
removed in subparts O, Y, DD, HH, and LL, a reduction in the annual
hourly labor estimate was assumed. Labor costs were applied to the
total annual hour estimates for each labor category to obtain the total
costs for each subpart.
2. Burden Associated With Revisions That Affect Applicability
    The EPA is proposing revisions that would affect the applicability
of two subparts of Part 98: Subpart V (Nitric Acid Production) and
subpart OO

(Suppliers of Industrial Greenhouse Gases). The proposed changes would
apply beginning in RY2018. These proposed changes are anticipated to
require reporting for four additional reporters under subpart V, and
five to ten additional reporters under subpart OO. (For the purposes of
estimating burden, an average of eight additional reporters were
assumed to be required to report under subpart OO of Part 98). The
majority of facilities within these industries already report under
Part 98; specifically, all four of the affected reporters under subpart
V already submit annual reports. The total incremental burden from
changes to applicability is $119,759 in the first year and $93,015 in
subsequent years ($2011). The incremental burden for the additional
reporters for subpart V includes first-year costs of $83,544 ($20,866
per facility) and subsequent year costs of $66,403 ($16,601 per
facility). The incremental burden for the additional reporters for
subpart OO includes first-year costs of $36,215 ($4,527 per facility)
and subsequent year costs of $26,612 ($3,327 per facility).
    To estimate the cost impacts for additional reporters, the recent
information collection request for the GHG reporting program \32\ was
used to obtain the first year average cost per facility that is
incurred from reporting under subparts V and OO (updated to $2011) and
the subsequent year burden. These average costs per facility include
labor costs, capital costs, and operation and maintenance costs. We
determined total reporting costs for each subpart by assigning these
costs to model facilities that are representative of each industry
sector. The total cost for each subpart was determined by multiplying
the model facilities cost by the number of affected facilities.
---------------------------------------------------------------------------

    \32\ See Supporting Statement Part A: Information Collection
Request for the Greenhouse Gas Reporting Program (U.S. EPA, 2013).
---------------------------------------------------------------------------

3. Burden Associated With Revisions to Monitoring Requirements for
Underground Coal Mines
    As discussed in section III.R.2 of this preamble, we are proposing
changes to the monitoring requirements of subpart FF of Part 98 to
remove the option to allow MSHA quarterly inspection reports to be used
as a source of data for monitoring methane liberated from ventilation
systems. Instead, facilities would be required to independently collect
their own grab samples or to use CEMS. The incremental increase in
costs for subpart FF reporters who would no longer have the option to
use MSHA data (and would need to collect monthly grab samples) are
$28,440 per facility in the first year and $14,609 per facility in
subsequent years ($2011); these revisions would affect approximately 65
reporters anticipated to use MSHA data annually. The proposed revisions
would have an industry-wide incremental cost of $1,848,571 in the first
year and $949,582 in subsequent years. The proposed changes would apply
beginning in RY2018.
    The incremental costs to the regulated industry resulting from
changes to the monitoring requirements for Underground Coal Mines are
based on the collection of independent grab samples in ventilation air.
Currently, about 50 percent of subpart FF reporters collect quarterly
gas samples. For mines that currently use MSHA data, the annual
incremental costs for taking grab samples was estimated as the cost of
taking the samples, less the avoided cost of obtaining, interpreting
and reporting MSHA data. We assumed that facilities would not install a
CEMS as a result of the monitoring changes.
    The costs resulting from removing the use of MSHA quarterly data
and requiring facilities to collect quarterly grab samples include
additional labor costs (i.e., the cost of labor by facility staff to
meet the rule's information collection requirements), capital costs
(e.g., the costs of anemometers or sample kits, for reporters that are
not currently conducting sampling), and operating and maintenance costs
(e.g., the cost associated with gas sample analysis). Hourly labor
costs were estimated based on the number of labor hours for developing
the sampling methodology and purchasing the devices, and the number of
hours required for sampling.

B. Additional Impacts of the Proposed Revisions to Part 98

    In addition to amendments that would revise the existing
applicability, monitoring, or reporting requirements of Part 98, the
EPA is proposing additional technical revisions and other
clarifications to several subparts in Part 98 that are not anticipated
to have a significant impact on burden. These include revisions
discussed in section III of this preamble that are intended to
streamline the rule requirements, including proposed revisions to
clarify and revise the requirements of Part 98 in order to focus GHGRP
and reporter resources on relevant data, to expand and clarify the
conditions under which a facility can cease reporting, or to clarify
requirements for facilities that report very little or no emissions,
and revisions that would improve the efficiency of the reporting and
verification process. These changes are anticipated to minimally reduce
burden for reporters.
    The EPA is also proposing revisions that are intended to improve
the quality of the rule but that would not impact burden, such as
amending calculation methods to improve the accuracy of the emissions
estimate (e.g., subparts I and Y); these proposed amendments would
increase the accuracy of reported emissions, but do not require
additional monitoring or data collection by reporters, and would have
no additional impact on burden.
    We are proposing, for certain subparts, to amend monitoring or
measurement methods to more closely align rule requirements with
different operating scenarios in the industry. Other proposed
amendments would provide flexibility for reporters and clarify
reporting requirements, as described in section II.C of this preamble.
These proposed amendments are anticipated to have no impact or
minimally decrease burden for reporters.
    The proposed revisions also include minor amendments, corrections,
and clarifications, including simple revisions of requirements such as
clarifying changes to definitions, calculation methodologies,
monitoring and quality assurance requirements, missing data procedures,
and reporting requirements. These proposed changes clarify Part 98 to
better reflect the EPA's intent, and would not present any additional
burden on reporters.
    A full discussion of the burden associated with the proposed
revisions for each subpart may be found in the memorandum, ``Assessment
of Burden Impacts of 2015 Revisions to the Greenhouse Gas Reporting
Rule,'' available in Docket Id. No. EPA-HQ-OAR-2015-0526.

VI. Statutory and Executive Order Reviews

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

    This action is a significant regulatory action that was submitted
to the Office of Management and Budget (OMB) for review because the
proposed amendments raise novel legal or policy issues. Any changes
made in response to OMB recommendations have been documented in the
docket. The EPA prepared an economic analysis of the potential costs
and benefits associated with this action. A copy of the analysis is
available in Docket Id. No. EPA-HQ-

OAR-2015-0526 and is briefly summarized in section V of this preamble.

B. Paperwork Reduction Act (PRA)

    The information collection activities in this proposed rule have
been submitted for approval to the OMB under the PRA. The Information
Collection Request (ICR) document that the EPA prepared has been
assigned EPA ICR number 2300.18. You can find a copy of the ICR in the
docket for this rule, and it is briefly summarized here.
    This action is proposing to amend specific provisions in the
Greenhouse Gas Reporting Rule to streamline and improve implementation
of the rule, improve the quality and consistency of the data collected
under the rule, and to clarify or propose minor updates to certain
provisions that have been the subject of questions from reporting
entities. These proposed amendments would improve the quality and
consistency of the data collected, as well as improve the efficiency of
the reporting process for both the EPA and reporters. The proposed
amendments are anticipated to increase burden in cases where the
proposed amendments would expand current applicability, monitoring, or
reporting, and are anticipated to decrease burden in cases where the
proposed amendments would streamline Part 98 to remove notification or
reporting requirements or simplify the data that must be reported.
    Specifically, this action proposes to amend the reporting
requirements to add or revise 118 data elements in 21 subparts of Part
98. These revisions are necessary to improve the quality of the data
collected under the GHGRP. The EPA is also proposing to remove 18 data
elements in five subparts, which would streamline rule requirements.
This action also proposes amendments that would affect the
applicability of two subparts of Part 98: subparts V (Nitric Acid
Production) and OO (Suppliers of Industrial Greenhouse Gases). These
amendments could increase the number of facilities required to report
under Part 98. Finally, this action proposes to revise the monitoring
requirements of subpart FF of Part 98 (Underground Coal Mines). The
proposed amendments would remove the option to allow Mine Safety and
Health Administration (MSHA) quarterly inspection reports to be used as
a source of data for monitoring methane liberated from ventilation
systems, and require facilities to independently collect their own grab
samples or to use continuous emissions monitoring. Impacts associated
with the proposed changes to the applicability, monitoring, and
reporting requirements are detailed in the memorandum ``Assessment of
Burden Impacts of 2015 Revisions to the Greenhouse Gas Reporting Rule''
(see Docket Id. No. EPA-HQ-OAR-2015-0526). Burden is defined at 5 CFR
1320.3(b).
    The total estimated incremental burden and cost associated with the
proposed revisions is 23,456 hours and $2,049,478 over the 3 years
covered by the information collection. These costs include $9,359 in
RY2016, $33,782 in RY2017, and $2,006,337 in RY2018, averaging $683,159
per year over the three years. The total estimated number of reporters
affected by the proposed amendments is 8,240. The proposed frequency of
response for these changes is once annually, with the exception of
certain data elements for subpart I which would be submitted once every
three years.
    The estimated incremental costs and hour burden associated with the
addition and revision of 118 data elements and the removal of 18 data
elements in 21 subparts is 682 hours and $39,234 annually ($2011),
including $9,359 from revisions first implemented in RY2016, $25,650
from revisions first implemented in RY2017, and $4,225 from revisions
first implemented in RY2018. For subpart I, the new data elements in
the proposed rule pertain to the triennial technology report required
under 40 CFR 98.96(y), which must first be submitted with RY2016
reports on or before March 31, 2017 and every three years thereafter.
For the purposes of estimating burden for the three years covered by
the information collection, the annual burden and costs associated with
these data elements (21 hours and $1,226) would apply for RY2016 only.
Therefore, the estimated incremental burden and cost associated with
reporting the new, revised, and removed data elements for all affected
source categories is 588 hours and $33,782 in RY2017, and 661 hours and
$38,007 for RY2018. The annual reporting burden associated with these
changes is estimated to average 0.17 hour per response, and the
estimated number of reporters affected is 7,127.
    The estimated incremental cost burden associated with additional
reporters to subparts V and OO is $119,759 in the first year (RY2018)
and $93,015 in subsequent years. The incremental burden for the
additional reporters for subpart V includes first-year costs of $83,544
and subsequent year costs of $66,403. The incremental burden for the
additional reporters for subpart OO includes first-year costs of
$36,215 and subsequent year costs of $26,612. The estimated number of
likely new respondents that would result from these amendments is 12,
including four additional reporters under subpart V, and an average of
eight additional reporters for subpart OO. The annual hourly burden for
these additional reporters is based on the annual average hourly burden
for existing reporters under subparts V and OO, which is 191 hours and
55 hours per reporter, respectively.
    The incremental increase in costs for subpart FF reporters from the
revised monitoring requirements are $28,440 per facility in the first
year (RY2018) and $14,609 in subsequent years ($2011). The proposed
revisions are estimated to affect 65 respondents and would have an
industry incremental cost of $1,848,571 in the first year (RY2018) and
$949,582 in subsequent years. The annual hourly burden associated with
these monitoring costs are 320 hours per reporter in the first year and
165 hours in subsequent years.
    An agency may not conduct or sponsor, and a person is not required
to respond to, a collection of information unless it displays a
currently valid OMB control number. The OMB control numbers for the
EPA's regulations in 40 CFR are listed in 40 CFR part 9.
    Submit your comments on the agency's need for this information, the
accuracy of the provided burden estimates and any suggested methods for
minimizing respondent burden to the EPA using the docket identified at
the beginning of this rule. You may also send your ICR-related comments
to OMB's Office of Information and Regulatory Affairs via email to
<EMAIL_ADDRESS>Attention: Desk Officer for the EPA.
Since OMB is required to make a decision concerning the ICR between 30
and 60 days after receipt, OMB must receive comments no later than
February 16, 2016. The EPA will respond to any ICR-related comments in
the final rule.

C. Regulatory Flexibility Act (RFA)

    I certify that this action will not have a significant economic
impact on a substantial number of small entities under the RFA. In
making this determination, the impact of concern is any significant
adverse economic impact on small entities. An agency may certify that a
rule will not have a significant economic impact on a substantial
number of small entities if the rule relieves regulatory burden, has no
net burden or otherwise has a positive economic effect on the small
entities subject to the rule. The impacts to small entities due to the
revisions was evaluated for each subpart. The EPA conducted a screening
assessment

comparing compliance costs for revisions to reporting requirements,
applicability to new reporters, and monitoring revisions under subparts
V, FF, and OO to specific receipts data for establishments owned by
small businesses in each industry. This ratio constitutes a ``sales''
test that computes the annualized compliance costs of this rule as a
percentage of sales and determines whether the ratio exceeds 1 percent.
The cost-to-sales ratios were constructed at the establishment level
(average reporting program costs per establishment/average
establishment receipts) for several business size ranges. We determined
that the cost-to-sales ratios are less than 1 percent for all
establishments in all business size ranges for subparts V, OO, and FF,
except the ratio for the 1-19 employee size range for facilities in
subpart FF was greater than 1 percent and less than 2 percent. The
sales test for this size category was also exceeded in the original EIA
\33\ and the EPA noted that mines owned by enterprises with less than
19 employees would be unlikely to be covered by this rule. Therefore,
we do not anticipate any impacts on small entities for subpart FF
reporters, and we have determined that there will not be a significant
economic impact to small entities for these three subparts. For all
other subparts, which are only affected by revisions for adding,
revising, or removing reporting requirements, we determined that these
facilities will experience annual impacts of approximately $11 per
facility. Because this cost is minimal, no small entity impacts are
anticipated for the remaining subparts.
---------------------------------------------------------------------------

    \33\ U.S. EPA. Economic Impact Analysis for the Mandatory
reporting of Greenhouse Gas Emissions: Subparts T, FF, TT, and II.
See Docket Id. No. EPA-HQ-OAR-2008-0508-2313. June 2010.
---------------------------------------------------------------------------

    Although there are no small entity impacts associated with these
proposed revisions, in the development of Part 98, the EPA took several
steps to reduce the impact on small entities. For example, the EPA
determined appropriate thresholds that reduced the number of small
businesses reporting. In addition, the EPA conducted several meetings
with industry associations to discuss regulatory options and the
corresponding burden on industry, such as recordkeeping and reporting.
The proposed rule amendments are minor technical corrections,
clarifying, and other amendments that will not impose any new
requirement on small entities that are not currently required by the
regulation of Part 98. We have therefore concluded that this action
will have no net regulatory burden for all directly regulated small
entities. The EPA continues to conduct significant outreach on the
GHGRP and maintains an ``open door'' policy for stakeholders to help
inform the EPA's understanding of key issues for the industries. We
continue to be interested in the potential impacts of the proposed rule
amendments on small entities and welcome comments on issues related to
such impacts.

D. Unfunded Mandates Reform Act (UMRA)

    This action does not contain an unfunded mandate of $100 million or
more as described in UMRA, 2 U.S.C. 1531-1538, and does not
significantly or uniquely affect small governments.
    The action implements mandate(s) specifically and explicitly set
forth in CAA section 114(a)(1) without the exercise of any policy
discretion by the EPA.

E. Executive Order 13132: Federalism

    This action does not have federalism implications. It will not have
substantial direct effects on the states, on the relationship between
the national government and the states, or on the distribution of power
and responsibilities among the various levels of government.

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

    This action does not have tribal implications as specified in
Executive Order 13175. The proposed rule amendments would not result in
any changes to the requirements that are not currently required for 40
CFR part 98. Thus, Executive Order 13175 does not apply to this action.
Consistent with the EPA Policy on Consultation and Coordination with
Indian Tribes, the EPA consulted with tribal officials during the
development of the rules for Part 98. A summary of that consultation is
provided in sections VIII.E and VIII.F of the preamble to the October
30, 2009 final GHG reporting rule.

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

    The EPA interprets Executive Order 13045 as applying only to those
regulatory actions that concern environmental health or safety risks
that the EPA has reason to believe may disproportionately affect
children, per the definition of ``covered regulatory action'' in
section 2-202 of the Executive Order. This action is not subject to
Executive Order 13045 because it does not concern an environmental
health risk or safety risk.

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

    This action is not a ``significant energy action'' because it is
not likely to have a significant adverse effect on the supply,
distribution or use of energy. Part 98 relates to monitoring,
reporting, and recordkeeping and does not impact energy supply,
distribution, or use. This final rule amends monitoring, calculation,
and reporting requirements for the GHGRP. In addition, the EPA is
proposing confidentiality determinations for new and revised data
elements proposed in this rulemaking and for certain existing data
elements for which a confidentiality determination has not previously
been proposed, or where the EPA has determined that the current
determination is no longer appropriate. These proposed amendments and
confidentiality determinations do not make any changes to the existing
monitoring, calculation, and reporting requirements under Part 98 that
affect the supply, distribution, or use of energy.

I. National Technology Transfer and Advancement Act

    This rulemaking does not involve technical standards.

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

    The EPA believes the human health or environmental risk addressed
by this action will not have potential disproportionately high and
adverse human health or environmental effects on minority, low-income
or indigenous populations because it does not affect the level of
protection provided to human health or the environment because it is a
rule addressing information collection and reporting procedures.

List of Subjects in 40 CFR Part 98

    Environmental protection, Administrative practice and procedure,
Greenhouse gases, Incorporation by reference, Reporting and
recordkeeping requirements, Suppliers.

    Dated: December 21, 2015.
Gina McCarthy,
Administrator.
    For the reasons stated in the preamble, the Environmental
Protection Agency proposes to amend title 40, chapter I, of the Code of
Federal Regulations as follows:

PART 98--MANDATORY GREENHOUSE GAS REPORTING

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

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

Subpart A--General Provision

0
2. Section 98.2 is amended by:
0
a. Revising paragraph (a)(1);
0
b. Revising paragraph (i)(1) through (3); and
0
c. Adding paragraphs (i)(4) through (6).
    The revisions and additions read as follows:

Sec.  98.2  Who must report?

    (a) * * *
    (1) A facility that contains any source category that is listed in
Table A-3 of this subpart. For these facilities, the annual GHG report
must cover stationary fuel combustion sources (subpart C of this part),
miscellaneous use of carbonates (subpart U of this part), and all
applicable source categories listed in Table A-3 and Table A-4 of this
subpart.
* * * * *
    (i) * * *
    (1) If reported emissions are less than 25,000 metric tons
CO2e per year for five consecutive years, then the owner or
operator may discontinue complying with this part provided that the
owner or operator submits a notification to the Administrator that
announces the cessation of reporting and explains the reasons for the
reduction in emissions. The notification shall be submitted no later
than March 31 of the year immediately following the fifth consecutive
year of emissions less than 25,000 tons CO2e per year. The
owner or operator must maintain the corresponding records required
under Sec.  98.3(g) for each of the five consecutive years prior to
notification of discontinuation of reporting and retain such records
for three years following the year that reporting was discontinued. The
owner or operator must resume reporting if annual emissions in any
future calendar year increase to 25,000 metric tons CO2e per
year or more.
    (2) If reported emissions are less than 15,000 metric tons
CO2e per year for three consecutive years, then the owner or
operator may discontinue complying with this part provided that the
owner or operator submits a notification to the Administrator that
announces the cessation of reporting and explains the reasons for the
reduction in emissions. The notification shall be submitted no later
than March 31 of the year immediately following the third consecutive
year of emissions less than 15,000 tons CO2e per year. The
owner or operator must maintain the corresponding records required
under Sec.  98.3(g) for each of the three consecutive years and retain
such records for three years prior to notification of discontinuation
of reporting following the year that reporting was discontinued. The
owner or operator must resume reporting if annual emissions in any
future calendar year increase to 25,000 metric tons CO2e per
year or more.
    (3) If the operations of a facility or supplier are changed such
that all applicable processes and operations subject to paragraphs
(a)(1) through (4) of this section cease to operate, then the owner or
operator may discontinue complying with this part for the reporting
years following the year in which cessation of such operations occurs,
provided that the owner or operator submits a notification to the
Administrator that announces the cessation of reporting and certifies
to the closure of all applicable processes and operations no later than
March 31 of the year following such changes. If one or more processes
or operations subject to paragraphs (a)(1) through (4) of this section
at a facility or supplier cease to operate, but not all applicable
processes or operations cease to operate, then the owner or operator is
exempt from reporting for any such processes or operations in the
reporting years following the reporting year in which cessation of the
process or operation occurs, provided that the owner or operator
submits a notification to the Administrator that announces the
cessation of reporting for the process or operation no later than March
31 of the year following such changes. This paragraph (i)(3) does not
apply to seasonal or other temporary cessation of operations. This
paragraph (i)(3) does not apply to facilities with municipal solid
waste landfills or industrial waste landfills, or to underground coal
mines except those with abandoned status as determined by the U.S. Mine
Safety & Health Administration. The owner or operator must resume
reporting for any future calendar year during which any of the GHG-
emitting processes or operations resume operation.
    (4) The provisions of paragraphs (i)(1) and (2) of this section
apply to suppliers subject to subparts LL through QQ of this part by
substituting the term ``quantity of GHG supplied'' for ``emissions.''
For suppliers, the provisions of paragraphs (i)(1) and (2) of this
section apply individually to each importer and exporter and
individually to each petroleum refinery, fractionator of natural gas
liquids, local natural gas distribution company, and producer of
CO2, N2O, or fluorinated greenhouse gases (e.g.,
a supplier of industrial greenhouse gases might qualify to discontinue
reporting as an exporter of industrial greenhouse gases but still be
required to report as an importer; or a company might qualify to
discontinue reporting as a supplier of industrial greenhouse gases
under subpart OO of this part but still be required to report as a
supplier of carbon dioxide under subpart PP of this part).
    (5) If the operations of a facility or supplier are changed such
that a process or operation no longer meets the ``Definition of Source
Category'' as specified in an applicable subpart, then the owner or
operator may discontinue complying with any such subpart for the
reporting years following the year in which change occurs, provided
that the owner or operator submits a notification to the Administrator
that announces the cessation of reporting for the process or operation
no later than March 31 of the year following such changes. The owner or
operator must resume complying with this part for the process or
operation starting in any future calendar year during which the process
or operation meets the ``Definition of Source Category'' as specified
in an applicable subpart.
    (6) If an entire facility or supplier is merged into another
facility or supplier that is already reporting GHG data under this
part, then the owner or operator may discontinue complying with this
part for the facility or supplier, provided that the owner or operator
submits a notification to the Administrator that announces the
discontinuation of reporting and the e-GGRT identification number of
the reconstituted facility no later than March 31 of the year following
such changes.
* * * * *
0
3. Section 98.3 is amended by:
0
a. Revising paragraph (c)(4)(iii) introductory text;
0
b. Adding paragraph (c)(4)(iii)(G); and
0
c. Revising paragraphs (c)(5)(ii), (c)(8), (d)(1)(i), and (h)(4).
    The revisions and additions read as follows:

Sec.  98.3  What are the general monitoring, reporting, recordkeeping
and verification requirements of this part?

* * * * *
    (c) * * *
    (4) * * *
    (iii) Annual emissions from each applicable source category,
expressed in metric tons of each applicable GHG

listed in paragraphs (c)(4)(iii)(A) through (F) of this section.
* * * * *
    (G) For each reported fluorinated GHG and fluorinated heat transfer
fluid, report the following identifying information:
    (1) Chemical name. If the chemical is not listed in Table A-1 of
this subpart, then use the method of naming organic chemical compounds
as recommended by the International Union of Pure and Applied Chemistry
(IUPAC).
    (2) The CAS registry number assigned by the Chemical Abstracts
Registry Service. If a CAS registry number is not assigned or is not
associated with a single fluorinated GHG or fluorinated heat transfer
fluid, then report an identification number assigned by EPA's Substance
Registry Services.
    (3) Linear chemical formula.
* * * * *
    (5) * * *
    (ii) Quantity of each GHG from each applicable supply category in
Table A-5 to this subpart, expressed in metric tons of each GHG. For
each reported fluorinated GHG, report the following identifying
information:
    (A) Chemical name. If the chemical is not listed in Table A-1 of
this subpart, then use the method of naming organic chemical compounds
as recommended by the International Union of Pure and Applied Chemistry
(IUPAC).
    (B) The CAS registry number assigned by the Chemical Abstracts
Registry Service. If a CAS registry number is not assigned or is not
associated with a single fluorinated GHG, then report an identification
number assigned by EPA's Substance Registry Services.
    (C) Linear chemical formula.
* * * * *
    (8) Each parameter for which a missing data procedure was used
according to the procedures of an applicable subpart and the total
number of hours in the year that a missing data procedure was used for
each parameter. Parameters include not only reported data elements, but
any data element required for monitoring and calculating emissions.
* * * * *
    (d) * * *
    (1) * * *
    (i) Monitoring methods currently used by the facility that do not
meet the specifications of a relevant subpart.
* * * * *
    (h) * * *
    (4) Notwithstanding paragraphs (h)(1) and (2) of this section, upon
request by the owner or operator, the Administrator may provide
reasonable extensions of the 45-day period for submission of the
revised report or information under paragraphs (h)(1) and (2) of this
section. If the Administrator receives a request for extension of the
45-day period, by email to an address prescribed by the Administrator
prior to the expiration of the 45-day period, the extension request is
deemed to be automatically granted for 30 days. The Administrator may
grant an additional extension beyond the automatic 30-day extension if
the owner or operator submits a request for an additional extension and
the request is received by the Administrator prior to the expiration of
the automatic 30-day extension, provided the request demonstrates that
it is not practicable to submit a revised report or information under
paragraphs (h)(1) and (2) of this section within 75 days. The
Administrator will approve the extension request if the request
demonstrates to the Administrator's satisfaction that it is not
practicable to collect and process the data needed to resolve potential
reporting errors identified pursuant to paragraphs (h)(1) or (2) of
this section within 75 days.
* * * * *
0
4. Section 98.4 is amended by adding paragraph (i)(6) to read as
follows:

Sec.  98.4  Authorization and responsibilities of the designated
representative.

* * * * *
    (i) * * *
    (6) A list of the subparts that the owners and operators anticipate
will be included in the annual GHG report. The list of potentially
applicable subparts is required only for an initial certificate of
representation that is submitted after [date of publication of the
final rule in the Federal Register] (i.e., for a facility or supplier
that previously was not registered under this part). The list of
subparts is not required for a revised COR.
* * * * *
0
5. Section 98.6 is amended by revising the definition for ``Gas
collection system or landfill gas collection system'', adding a
definition for ``Reporting year'' in alphabetical order, and revising
the definition for ``Ventilation hole or shaft'' to read as follows:

Sec.  98.6  Definitions.

* * * * *
    Gas collection system or landfill gas collection system means a
system of pipes used to collect landfill gas from different locations
in the landfill by means of a fan or similar mechanical draft equipment
(forced convection) to a single location for treatment (thermal
destruction) or use. Landfill gas collection systems may also include
knock-out or separator drums and/or a compressor. A single landfill may
have multiple gas collection systems. Landfill gas collection systems
do not include ``passive'' systems, whereby landfill gas flows
naturally (without forced convection) to the surface of the landfill
where an opening or pipe (vent) is installed to allow for the flow of
landfill gas to the atmosphere or to a remote flare installed to
combust landfill gas that is passively emitted from the vent. Landfill
gas collection systems also do not include ``active venting'' systems,
whereby landfill gas is conveyed to the surface of the landfill using
forced convection, but the landfill gas is never recovered or thermally
destroyed prior to release to the atmosphere.
* * * * *
    Reporting year means the calendar year during which the GHG data
are required to be collected for purposes of the annual GHG report. For
example, reporting year 2014 is January 1, 2014 through December 31,
2014, and the annual report for reporting year 2014 is submitted to EPA
on March 31, 2015.
* * * * *
    Ventilation hole or shaft means a vent hole, shaft, mine portal,
adit or other mine entrance or exits employed at an underground coal
mine to serve as the outlet or conduit to move air from the ventilation
system out of the mine.
* * * * *
0
6. Section 98.7 is amended by revising paragraphs (e)(33) and (l)(1) to
read as follows:

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

* * * * *
    (e) * * *
    (33) ASTM D6866-12 Standard Test Methods for Determining the
Biobased Content of Solid, Liquid, and Gaseous Samples Using
Radiocarbon Analysis, IBR approved for Sec. Sec.  98.34(d), 98.34(e),
and 98.36(e).
* * * * *
    (l) * * *
    (1) Coal Mine Safety and Health General Inspection Procedures
Handbook, Handbook Number: PH13-V-1, February 2013, IBR approved for
Sec.  98.324(b).
* * * * *
0
7. Table A-3 to Subpart A of Part 98 is amended by revising the entries
``Source Categories Applicable in 2010 and Future Years'' and
``Additional Source Categories Applicable in 2011 and Future Years'' to
read as follows:

    Table A-3 to Subpart A of Part 98--Source Category List for Sec.
                               98.2(a)(1)
------------------------------------------------------------------------

-------------------------------------------------------------------------
Source Categories \a\ Applicable in Reporting Year 2010 and Future Years

                              * * * * * * *
------------------------------------------------------------------------
Additional Source Categories \a\ Applicable in Reporting Year 2011 and
 Future Years
------------------------------------------------------------------------

                              * * * * * * *
------------------------------------------------------------------------
\a\ Source categories are defined in each applicable subpart.

0
8. Table A-4 to Subpart A of Part 98 is amended by revising the entries
``Source Categories Applicable in 2010 and Future Years'' and
``Additional Source Categories Applicable in 2011 and Future Years'' to
read as follows:

   Table A-4 to Subpart A--Source Category List for Sec.   98.2(a)(2)
------------------------------------------------------------------------

-------------------------------------------------------------------------
Source Categories \a\ Applicable in Reporting Year 2010 and Future Years

                              * * * * * * *
Additional Source Categories \a\ Applicable in Reporting Year 2011 and
 Future Years
------------------------------------------------------------------------

                              * * * * * * *
------------------------------------------------------------------------
\a\ Source categories are defined in each applicable subpart.

0
9. Table A-5 to Subpart A of Part 98 is amended by:
0
a. Revising the entry ``Supplier Categories Applicable in 2010 and
Future Years'';
0
b. Revising the entries associated with ``Industrial greenhouse gas
suppliers (subpart OO)''; and
0
c. Revising the entry ``Additional Supplier Categories Applicable in
2011 and Future Years.''
    The revisions read as follows:

  Table A-5 to Subpart A--Supplier Category List for Sec.   98.2(a)(4)
------------------------------------------------------------------------

-------------------------------------------------------------------------
Supplier Categories \a\ Applicable in Reporting Year 2010 and Future
 Years

                              * * * * * * *
Industrial greenhouse gas suppliers (subpart OO):
    (A) All producers of industrial greenhouse gases and fluorinated
     heat transfer fluids.
    (B) Importers of industrial greenhouse gases and fluorinated heat
     transfer fluids with annual bulk imports of N2O, fluorinated GHG,
     fluorinated heat transfer fluids, and CO2 that in combination are
     equivalent to 25,000 metric tons CO2e or more.
    (C) Exporters of industrial greenhouse gases with annual bulk
     exports of N2O, fluorinated GHG, fluorinated heat transfer fluids,
     and CO2 that in combination are equivalent to 25,000 metric tons
     CO2e or more.
    (D) Facilities that destroy 25,000 mtCO2e or more of fluorinated
     GHGs or fluorinated heat transfer fluids annually.

                              * * * * * * *
Additional Supplier Categories Applicable \a\ in Reporting Year 2011 and
 Future Years

                              * * * * * * *
------------------------------------------------------------------------
\a\ Suppliers are defined in each applicable subpart.

Subpart C--General Stationary Fuel Combustion Sources

0
10. Section 98.33 is amended by revising parameters
``(HHV)I,'' ``(Fuel)I,'' and ``n'' of Equation C-
2b in paragraph (a)(2)(ii)(A) and revising paragraphs (a)(5)(i)(C),
(a)(5)(ii)(C), and (a)(5)(iii)(C) to read as follows:

Sec.  98.33  Calculating GHG emissions.

* * * * *
    (a) * * *
    (2) * * *
    (ii) * * *
    (A) * * *
* * * * *

(HHV)I = Measured high heat value of the fuel, for sample
period ``i'' (which may be the arithmetic average of multiple
determinations), or, if applicable, an appropriate substitute data
value (mmBtu per mass or volume).
(Fuel)I = Mass or volume of the fuel combusted during the
sample period ``i,'' (e.g., monthly, quarterly, semi-annually, or by
lot) from company records (express mass in short tons for solid
fuel, volume in standard cubic feet (e.g., for gaseous fuel, and
volume in gallons for liquid fuel).
n = Number of sample periods in the year.

* * * * *
    (5) * * *
    (i) * * *
    (C) Divide the cumulative annual CO2 mass emissions
value by 1.1023 to convert it to metric tons.
* * * * *
    (ii) * * *
    (C) Divide the cumulative annual CO2 mass emissions
value by 1.1023 to convert it to metric tons.
    (iii) * * *
    (C) Divide the cumulative annual CO2 mass emissions
value by 1.1023 to convert it to metric tons.
* * * * *
0
11. Section 98.34 is amended by revising paragraphs (d) and (e) to read
as follows:

Sec.  98.34  Monitoring and QA/QC requirements.

* * * * *
    (d) Except as otherwise provided in Sec.  98.33(b)(1)(vi) and
(vii), when municipal solid waste (MSW) is either the primary fuel
combusted in a unit or the only fuel with a biogenic component
combusted in the unit, determine the biogenic portion of the
CO2 emissions using ASTM D6866-12 Standard Test Methods for
Determining the Biobased Content of Solid, Liquid, and Gaseous Samples
Using Radiocarbon Analysis (incorporated by reference, see Sec.  98.7)
and ASTM D7459-08 Standard Practice for Collection of Integrated
Samples for the Speciation of Biomass (Biogenic) and Fossil-Derived
Carbon Dioxide Emitted from Stationary Emissions Sources (incorporated
by reference, see Sec.  98.7). Perform the ASTM D7459-08 sampling and
the ASTM D6866-12 analysis at least once in every calendar quarter in
which MSW is combusted in the unit. Collect each gas sample during
normal unit operating conditions for at least 24 total (not necessarily
consecutive) hours, or longer if the facility deems it necessary to
obtain a representative sample. Notwithstanding this requirement, if
the types of fuels combusted and their relative proportions are
consistent throughout the year, the minimum required sampling time may
be reduced to 8 hours if at least two 8-hour samples and one 24-hour
sample are collected under normal operating conditions, and arithmetic
average of the biogenic fraction of the flue gas from the 8-hour
samples (expressed as a decimal) is within 5 percent of the
biogenic fraction from the 24-hour test. There must be no overlapping
of the 8-hour and 24-hour test periods. Document the results of the
demonstration in the unit's monitoring plan. If the types of fuels and
their relative proportions are not consistent throughout the year, an
optional sampling approach that facilities may wish to consider to
obtain a more representative sample is to collect an integrated sample
by extracting a small amount of flue gas (e.g., 1 to 5 cc) in each unit
operating hour during the quarter. Separate the total annual
CO2 emissions into the biogenic and non-biogenic fractions
using the average proportion of biogenic emissions of all samples
analyzed during the reporting year. Express the results as a decimal
fraction (e.g., 0.30, if 30 percent of the CO2 is biogenic).
When MSW is the primary fuel for multiple units at the facility, and
the units are fed from a common fuel source, testing at only one of the
units is sufficient.
    (e) For other units that combust combinations of biomass fuel(s)
(or heterogeneous fuels that have a biomass component, e.g., tires) and
fossil (or other non-biogenic) fuel(s), in any proportions, ASTM D6866-
12 (incorporated by reference, see Sec.  98.7) and ASTM D7459-08
(incorporated by reference, see Sec.  98.7) may be used to determine
the biogenic portion of the CO2 emissions in every calendar
quarter in which biomass and non-biogenic fuels are co-fired in the
unit. Follow the procedures in paragraph (d) of this section. If the
primary fuel for multiple units at the facility consists of tires, and
the units are fed from a common fuel source, testing at only one of the
units is sufficient.
* * * * *
0
12. Section 98.36 is amended by adding paragraphs (c)(1)(iii) and
(c)(3)(ii) and revising paragraphs (e)(2)(i), (e)(2)(x) introductory
text, and (e)(2)(xi) to read as follows:

Sec.  98.36  Data reporting requirements.

* * * * *
    (c) * * *
    (1) * * *
    (iii) Cumulative maximum rated heat input capacity of the group
(mmBtu/hr). The cumulative maximum rated heat input capacity shall be
determined as the sum of the maximum rated heat input capacities for
all units in the group, excluding units less than 10 (mmBtu/hr).
* * * * *
    (3) * * *
    (ii) Cumulative maximum rated heat input capacity of the units
served by the common pipe (mmBtu/hr). The cumulative maximum rated heat
input capacity shall be determined as the sum of the maximum rated heat
input capacities for all units served by the common pipe, excluding
units less than 10 (mmBtu/hr).
* * * * *
    (e) * * *
    (2) * * *
    (i) For the Tier 1 Calculation Methodology, report:
    (A) The total quantity of each type of fuel combusted in the unit
or group of aggregated units (as applicable) during the reporting year,
in short tons for solid fuels, gallons for liquid fuels and standard
cubic feet for gaseous fuels, or, if applicable, therms or mmBtu for
natural gas.
    (B) If applicable, the moisture content used to calculate the wood
and wood residuals wet basis HHV for use in Equations C-1 and C-8, in
percent.
* * * * *
    (x) When ASTM methods D7459-08 (incorporated by reference, see
Sec.  98.7) and D6866-12 (incorporated by reference, see Sec.  98.7)
are used to determine the biogenic portion of the annual CO2
emissions from MSW combustion, as described in Sec.  98.34(d), report:
* * * * *
    (xi) When ASTM methods D7459-08 (incorporated by reference, see
Sec.  98.7) and D6866-12 (incorporated by reference, see Sec.  98.7)
are used in accordance with Sec.  98.34(e) to determine the biogenic
portion of the annual CO2 emissions from a unit that co-
fires biogenic fuels (or partly-biogenic fuels, including tires if you
are electing to report biogenic CO2 emissions from tire
combustion) and non-biogenic fuels, you shall report the results of
each quarterly sample analysis, expressed as a decimal fraction (e.g.,
if the biogenic fraction of the CO2 emissions is 30 percent,
report 0.30).
* * * * *
0
13. Section 98.37 is amended by revising paragraph (a) and adding
paragraph (b)(37) to read as follows:

Sec.  98.37  Records that must be retained.

* * * * *
    (a) The applicable records specified in Sec. Sec.  98.34(f),
98.35(b), and 98.36(e).
* * * * *
    (b) * * *
    (37) Moisture content used to calculate the wood and wood residuals
wet basis HHV (percent), if applicable (Equations C-1 and C-8).
0
14. Table C-1 to Subpart C of Part 98 is amended by:
0
a. Removing the entries ``Petroleum Coke'' under ``Petroleum
products'', ``Petroleum Coke'' under ``Other fuels--solid'', and
``Propane Gas'' under ``Other fuels--gaseous'';
0
b. Removing the heading ``Petroleum products'' in the ``Fuel type''
column and adding in its place the heading ``Petroleum products--
liquid''; and
0
c. Adding heading ``Petroleum products--solid'' and its entry
``Petroleum Coke'',and heading ``Petroleum products--gaseous'', and its
entry ``Propane Gas'' after the entry ``Crude Oil''.
    The revisions, and additions read as follows:

  Table C-1 to Subpart C of Part 98--Default CO[ihel2] Emission Factors
             and High Heat Values for Various Types of Fuel
------------------------------------------------------------------------
                                   Default high heat      Default CO2
            Fuel type                    value          emission factor
------------------------------------------------------------------------

                              * * * * * * *
------------------------------------------------------------------------
Petroleum products--liquid......  mmBtu/gallon......  kg CO2/mmBtu

                              * * * * * * *
------------------------------------------------------------------------
Petroleum products--solid.......  mmBtu/short ton...  kg CO2/mmBtu
Petroleum Coke..................  30.00.............  102.41
Petroleum products--gaseous.....  mmBtu/scf.........  kg CO2/mmBtu
Propane Gas.....................  2.516 x 10-\3\....  61.46
------------------------------------------------------------------------

                              * * * * * * *
------------------------------------------------------------------------
------------------------------------------------------------------------

* * * * *
0
15. Table C-2 to Subpart C of Part 98 is amended by:
0
a. Removing the entry ``Petroleum (All fuel types in Table C-1)'' and
adding in its place the entry ``Petroleum Products (All fuel types in
Table C-1)'';
0
b. Removing the entry ``Municipal Solid Waste'' and adding in its place
the entry '' Other Fuels--Solid'';
0
c. Removing the entry ``Tires''.
    The additions read as follows:

   Table C-2 to Subpart C of Part 98--Default CH[ihel4] and N[ihel2]O
               Emission Factors for Various Types of Fuel
------------------------------------------------------------------------
                                   Default CH[ihel4]   Default N[ihel2]O
                                    emission factor     emission factor
            Fuel type               (kg CH[ihel4]/      (kg N[ihel2]O/
                                        mmBtu)              mmBtu)
------------------------------------------------------------------------

                              * * * * * * *
------------------------------------------------------------------------
Petroleum Products (All fuel      3.0 x 10-\03\.....  6.0 x 10-\04\
 types in Table C-1).
------------------------------------------------------------------------

                              * * * * * * *
------------------------------------------------------------------------
Other Fuels--Solid..............  3.2 x 10-\02\.....  4.2 x 10-\03\
------------------------------------------------------------------------

                              * * * * * * *
------------------------------------------------------------------------
------------------------------------------------------------------------

* * * * *

Subpart E--Adipic Acid Production

0
16. Section 98.53 is amended by revising paragraph (a)(2) to read as
follows:

Sec.  98.53  Calculating GHG emissions.

    (a) * * *
    (2) Request Administrator approval for an alternative method of
determining N2O emissions according to paragraphs (a)(2)(i)
through (iv) of this section.
    (i) If you received Administrator approval for an alternative
method of determining N2O emissions in the previous
reporting year and your methodology is unchanged, your alternative
method is automatically approved for the next reporting year.
    (ii) You must notify the EPA of your use of a previously approved
alternative method in your annual report.
    (iii) Otherwise, you must submit the request within 45 days
following promulgation of this subpart or within the first 30 days of
each subsequent reporting year.
    (iv) If the Administrator does not approve your requested
alternative method within 150 days of the end of the reporting year,
you must determine the N2O emissions for the current
reporting period using the procedures specified in paragraph (a)(1) of
this section.
* * * * *
0
17. Section 98.56 is amended by revising paragraph (f) to read as
follows:

Sec.  98.56  Data reporting requirements.

* * * * *
    (f) Types of abatement technologies used and date of installation
for each (if applicable).
* * * * *

Subpart F--Aluminum Production

0
18. Section 98.65 is amended by revising paragraph (a) introductory
text and Equation F-8 to read as follows:

Sec.  98.65  Procedures for estimating missing data.

* * * * *
    (a) Where anode or paste consumption data are missing,
CO2 emissions can be estimated from aluminum production by
using Equation F-9 of this section.

[GRAPHIC] [TIFF OMITTED] TP15JA16.000

* * * * *
0
19. Section 98.66 is amended by adding paragraph (c)(2) and revising
paragraph (c)(3) to read as follows:

Sec.  98.66  Data reporting requirements.

* * * * *
    (c) * * *
    (2) Anode effect minutes per cell-day (AE-mins/cell-day), anode
effect frequency (AE/cell-day), anode effect duration (minutes). (Or
anode effect overvoltage factor ((kg CF4/metric ton Al)/(mV/cell day)),
potline overvoltage (mV/cell day), current efficiency (%).)
    (3) Smelter-specific slope coefficients (or overvoltage emission
factors) and the last date when the smelter-specific slope coefficients
(or overvoltage emission factors) were measured.
* * * * *

Subpart G--Ammonia Manufacturing

0
20. Section 98.74 is amended by adding paragraph (f) to read as
follows:

Sec.  98.74  Monitoring and QA/QC requirements.

* * * * *
    (f) You may use company records or an engineering estimate to
determine the annual ammonia production and the annual methanol
production.
* * * * *
0
21. Section 98.76 is amended by:
0
a. Revising paragraph (a) introductory text;
0
b. Adding paragraph (a)(3); and
0
c. Adding paragraphs (b)(2) and (7), and revising paragraph (b)(15).
    The revisions and additions read as follows:

Sec.  98.76  Data reporting requirements.

* * * * *
    (a) If a CEMS is used to measure CO2 emissions, then you
must report the relevant information required under Sec.  98.36 for the
Tier 4 Calculation Methodology and the information in paragraphs (a)(1)
through (3) of this section:
* * * * *
    (3) Annual ammonia production (metric tons, sum of all process
units reported within subpart G of this part).
    (b) * * *
    (2) Annual quantity of each type of feedstock consumed for ammonia
manufacturing (scf of feedstock or gallons of feedstock or kg of
feedstock).
* * * * *
    (7) Annual average carbon content of each type of feedstock
consumed.
* * * * *
    (15) Annual methanol production for each process unit (metric
tons), regardless of whether the methanol is subsequently destroyed,
vented, or sold as product.

Subpart I--Electronics Manufacturing

0
22. Section 98.93 is amended by:
0
a. Revising paragraph (a)(1) introductory text;
0
b. Revising parameters ``Nil'' and ``Fil'' of
Equation I-12 in paragraph (d);
0
c. Revising paragraphs (i)(1)(ii) and (i)(1)(iv);
0
d. Revising Equation I-17 in paragraph (i)(3)(ii);
0
e. Revising parameter ``dif'' of Equation I-19 in paragraph
(i)(3)(ii);
0
f. Revising parameter ``dkf'' of Equation I-20 in paragraph
(i)(3)(iv);
0
g. Revising parameter ``dif'' of Equation I-21 in paragraph
(i)(3)(v);
0
h. Revising parameter ``dkf'' of Equation I-22 in paragraph
(i)(3)(vi); and
0
i. Revising paragraph (i)(3)(viii) and paragraph (i)(4) introductory
text.
    The revisions read as follows:

Sec.  98.93  Calculating GHG emissions.

    (a) * * *
    (1) If you manufacture semiconductors, you must adhere to the
procedures in paragraphs (a)(1)(i) through (iii) of this section. You
must calculate annual emissions of each input gas and of each by-
product gas using Equations I-6 and I-7 of this subpart, respectively.
If your fab uses less than 50 kg of a fluorinated GHG in one reporting
year, you may calculate emissions as equal to your fab's annual
consumption for that specific gas as calculated in Equation I-11 of
this subpart, plus any by-product emissions of that gas calculated
under paragraph (a) of this section.
* * * * *
    (d) * * *
* * * * *

    Nil = Number of containers of size and type l used at
the fab and returned to the gas distributor containing the standard
heel of input gas i.
    Fil = Full capacity of containers of size and type l
containing input gas i (kg).

* * * * *
    (i) * * *
    (1) * * *
    (ii) You must use representative data from the previous reporting
year to estimate the consumption of input gas i as calculated in
Equation I-13 of this subpart and the fraction of input gas i and by-
product gas k destroyed in abatement systems for each stack system as
calculated by Equations I-24A and I-24B of this subpart. If you were
not required to submit an annual report under subpart I for the
previous reporting year and data from the previous reporting year are
not available, you may estimate the consumption of input gas i and the
fraction of input gas i destroyed in abatement systems based on
representative operating data from a period of at least 30 days in the
current reporting year. When calculating the consumption of input gas i
using Equation I-13 of this subpart, the term ``fij'' is
replaced with the ratio of the number of tools using input gas i that
are vented to the stack system for which you are calculating the
preliminary estimate to the total number of tools in the fab using
input gas i, expressed as a decimal fraction. You may use this approach
to determining fij only for this preliminary estimate.
* * * * *
    (iv) If you anticipate an increase or decrease in annual
consumption or emissions of any fluorinated GHG, or the number of tools
connected to abatement systems greater than 10 percent for the current
reporting year compared to the previous reporting year, you must
account for the anticipated change in your preliminary estimate. You
may account for such a change using a quantifiable metric (e.g., the
ratio of the number of tools that are expected to be vented to the
stack system in the current year as compared to the previous reporting
year, ratio of the expected number of wafer starts in the current
reporting year as compared to the previous reporting year), engineering
judgment, or other industry standard practice.
* * * * *
    (3) * * *
    (ii) * * *

[GRAPHIC] [TIFF OMITTED] TP15JA16.001

* * * * *
    (iii) * * *
* * * * *
    dif = Fraction of fluorinated GHG input gas i
destroyed or removed in abatement systems connected to process tools
in fab f, as calculated in Equation I-24A of this subpart (expressed
as decimal fraction). If the stack system does not have abatement
systems on the tools vented to the stack system, the value of this
parameter is zero.
* * * * *
    (iv) * * *
* * * * *
    dkf = Fraction of fluorinated GHG by-product gas k
destroyed or removed in abatement systems connected to process tools
in fab f, as calculated in Equation I-24B of this subpart (expressed
as decimal fraction).
* * * * *
    (v) * * *
* * * * *
    dif = Fraction of fluorinated GHG input gas i
destroyed or removed in abatement systems connected to process tools
in fab f that are included in the stack testing option, as
calculated in Equation I-24A of this subpart (expressed as decimal
fraction).
* * * * *
    (vi) * * *
* * * * *
    dkf = Fraction of fluorinated GHG by-product k
destroyed or removed in abatement systems connected to process tools
in fab f that are included in the stack testing option, as
calculated in Equation I-24B of this subpart (expressed as decimal
fraction).
* * * * *
    (viii) When using the stack testing option described in paragraph
(i) of this section, you must calculate the weighted-average fraction
of each fluorinated input gas i and each fluorinated by-product gas k
destroyed or removed in abatement systems for each fab f, as
applicable, by using Equation I-24A (for input gases) and Equation I-
24B (for by-product gases) of this subpart.
[GRAPHIC] [TIFF OMITTED] TP15JA16.002

    Where:
    dif = The average weighted fraction of fluorinated
GHG input gas i destroyed or removed in abatement systems in fab f
(expressed as a decimal fraction).
    dkf = The average weighted fraction of fluorinated
GHG by-product gas k destroyed or removed in abatement systems in
fab f (expressed as a decimal fraction).
    Cijf = The amount of fluorinated GHG input gas i
consumed for process type j fed into abatement systems in fab f as
calculated using Equation I-13 of this subpart (kg).
    (1--Uij) = The default emission factor for input gas
i used in process type j, from applicable Table I-3 to I-7 of this
subpart.
    Bijk = The default by-product gas formation rate
factor for by-product gas k from input gas i used in process type j,
from applicable Table I-3 to I-7 of this subpart.
    DREij = Destruction or removal efficiency for
fluorinated GHG input gas i in abatement systems connected to
process tools where process type j is used (expressed as a decimal
fraction) determined according to Sec.  98.94(f).
    DREjk = Destruction or removal efficiency for
fluorinated GHG by-product gas k in abatement systems connected to
process tools where input gas i is used in process type j (expressed
as a decimal fraction) determined according to Sec.  98.94(f).
    f = fab.
    i = Fluorinated GHG input gas.
    j = Process type.
    (4) Method to calculate emissions from stack systems that are not
tested. You must calculate annual fab-level emissions of each
fluorinated GHG input gas and by-product gas for those fluorinated GHG
listed in paragraphs (i)(4)(i) and (ii) of this section using default
utilization and by-product formation rates as shown in Tables I-11, I-
12, I-13, I-14, or I-15 of this subpart, as applicable, and by using
Equations I-8, I-9, and I-13 of this subpart. When using Equations I-8,
I-9, and I-13 of this subpart to fulfill the requirements of this
paragraph, you must use, in place of the term Cij in each
equation, the total consumption of each fluorinated GHG meeting the
criteria in paragraph (i)(4)(i) of this section or that is used in
tools vented to the stack systems that meet the criteria in paragraph
(i)(4)(ii) of this section. You must use, in place of the term
aij, the fraction of fluorinated GHG meeting the criteria in
paragraph (i)(4)(i) of this section used in tools with abatement
systems or that is used in tools with abatement systems that are vented
to the stack systems that meet the criteria in paragraph (i)(4)(ii) of
this section. You also must use the results of Equations I-24A and I-
24B of this subpart in place of the terms dij in Equation I-
8 of this subpart and djk in Equation I-9 of this subpart,
respectively, and use the results of Equation I-23 of this subpart in
place of the results of Equation I-15 of this subpart for the term
UTij.
* * * * *
0
23. Section 98.94 is amended by revising paragraph (f) introductory
text and paragraph (j)(5)(ii) introductory text to read as follows:

Sec.  98.94  Monitoring and QA/QC requirements.

* * * * *
    (f) If your fab employs abatement systems and you elect to reflect
emission reductions due to these systems, or if your fab employs
abatement systems designed for fluorinated GHG abatement and you elect
to calculate fluorinated GHG emissions using the stack test method
under Sec.  98.93(i), you must comply with the requirements of
paragraphs (f)(1) through (3) of this section. If you use an average of
properly measured destruction or removal efficiencies for a gas and
process sub-type or process type combination, as applicable, in your
emission calculations under Sec.  98.93(a), (b), and/or (i), you must
also adhere to procedures in paragraph (f)(4) of this section.
* * * * *
    (j) * * *

    (5) * * *
    (ii) Criteria to test less frequently. After the first 3 years of
annual testing, you may calculate the relative standard deviation of
the emission factors for each fluorinated GHG included in the test and
use that analysis to determine the frequency of any future testing. As
an alternative, you may conduct all three tests in less than 3 calendar
years for purposes of this paragraph (j)(5)(ii), but this does not
relieve you of the obligation to conduct subsequent annual testing if
you do not meet the criteria to test less frequently. If the criteria
specified in paragraphs (j)(5)(ii)(A) and (B) of this section are met,
you may use the arithmetic average of the three emission factors for
each fluorinated GHG and fluorinated GHG by-product for the current
year and the next 4 years with no further testing unless your fab
operations are changed in a way that triggers the re-test criteria in
paragraph (j)(8) of this section. In the fifth year following the last
stack test included in the previous average, you must test each of the
stack systems for which testing is required and repeat the relative
standard deviation analysis using the results of the most recent three
tests (i.e., the new test and the two previous tests conducted prior to
the 4 year period). If the criteria specified in paragraphs
(j)(5)(ii)(A) and (B) of this section are not met, you must use the
emission factors developed from the most recent testing and continue
annual testing. You may conduct more than one test in the same year,
but each set of emissions testing for a stack system must be separated
by a period of at least 2 months. You may repeat the relative standard
deviation analysis using the most recent three tests, including those
tests conducted prior to the 4 year period, to determine if you are
exempt from testing for the next 4 years.
* * * * *
0
24. Section 98.96 is amended by:
0
a. Revising paragraphs (c)(2), (d), and (e);
0
b. Revising parameters ``dif'' and ``dkf'' of Equation I-28 in
paragraph (r)(2); and
0
c. Revising paragraph (y)(2)(iv).
    The revisions read as follows:

Sec.  98.96  Data reporting requirements.

* * * * *
    (c) * * *
    (2) When you use the procedures specified in Sec.  98.93(a), each
fluorinated GHG emitted from each process type or process sub-type as
calculated in Equations I-8 and I-9 of this subpart, as applicable.
* * * * *
    (d) The method of emissions calculation used in Sec.  98.93 for
each fab.
    (e) Annual production in terms of substrate surface area (e.g.,
silicon, PV-cell, glass) for each fab, including specification of the
substrate.
* * * * *
    (r) * * *
    (2) * * *
* * * * *
dif = Fraction of fluorinated GHG i destroyed or removed
in abatement systems connected to process tools in fab f, as
calculated from Equation I-24A of this subpart, which you used to
calculate total emissions according to the procedures in Sec.
98.93(i)(3) (expressed as a decimal fraction).
* * * * *
dkf = Fraction of fluorinated GHG by-product k destroyed
or removed in abatement systems connected to process tools in fab f,
as calculated from Equation I-24B of this subpart, which you used to
calculate total emissions according to the procedures in Sec.
98.93(i)(3) (expressed as a decimal fraction).
* * * * *
    (y) * * *
    (2) * * *
    (iv) It must provide any utilization and by-product formation rates
and/or destruction or removal efficiency data that have been collected
in the previous 3 years that support the changes in semiconductor
manufacturing processes described in the report. For any utilization,
by-product formation rate, and/or destruction or removal efficiency
data submitted, the report must describe, where available: methods used
for the measurements, wafer size, film type being manufactured,
substrate type, the linewidth or technology node, process type, process
subtype for chamber clean processes, the input gases used and measured,
the utilization rates measured, and the by-product formation rates
measured.
* * * * *
0
25. Section 98.97 is amended by revising paragraphs (d)(5) introductory
text and (d)(7) to read as follows:

Sec.  98.97  Records that must be retained.

* * * * *
    (d) * * *
    (5) In addition to the inventory specified in Sec.  98.96(p), the
information in paragraphs (d)(5)(i) through (iii) of this section:
* * * * *
    (7) Records of all inputs and results of calculations made to
determine the average weighted fraction of each gas destroyed or
removed in the abatement systems for each stack system using Equations
I-24A and I-24B of this subpart, if applicable. The inputs should
include an indication of whether each value for destruction or removal
efficiency is a default value or a measured site-specific value.
* * * * *
0
26. Table I-3 of subpart I is amended to read as follows:

      Table I-3 to Subpart I of Part 98--Default Emission Factors (1-Uij) for Gas Utilization Rates (Uij) and By-Product Formation Rates (Bijk) for
                                              Semiconductor Manufacturing for 150mm and 200 mm Wafer Sizes
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                                Process gas i
       Process type/sub-type        --------------------------------------------------------------------------------------------------------------------
                                       CF4      C2F6     CHF3    CH2F2    C2HF5     CH3F     C3F8     C4F8     NF3      SF6      C4F6     C5F8    C4F8O
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                 ETCHING/WAFER CLEANING
--------------------------------------------------------------------------------------------------------------------------------------------------------
1-Ui...............................     0.81     0.72     0.51     0.13    0.064     0.70       NA     0.14     0.19     0.55     0.17    0.072       NA
BCF4...............................       NA     0.10    0.085    0.079    0.077       NA       NA     0.11   0.0040     0.13     0.13       NA       NA
BC2F6..............................    0.046       NA    0.030    0.025    0.024   0.0034       NA    0.037    0.025     0.11     0.11    0.014       NA
BC4F6..............................       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA
BC4F8..............................       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA
BC3F8..............................       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA
BCF8...............................   0.0012       NA   0.0012       NA       NA       NA       NA   0.0086       NA       NA       NA       NA       NA
BCHF3..............................     0.10    0.047       NA    0.049       NA       NA       NA    0.040       NA   0.0012    0.066   0.0039       NA
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                    CHAMBER CLEANING
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                In situ plasma cleaning:
--------------------------------------------------------------------------------------------------------------------------------------------------------
1-Ui...............................     0.92     0.55       NA       NA       NA       NA     0.40     0.10     0.18       NA       NA       NA     0.14

BCF4...............................       NA     0.19       NA       NA       NA       NA     0.20     0.11    0.050       NA       NA       NA     0.13
BCF6...............................       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA    0.045
BC3F8..............................       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                 Remote plasma cleaning:
--------------------------------------------------------------------------------------------------------------------------------------------------------
1-Ui...............................       NA       NA       NA       NA       NA       NA       NA       NA    0.017       NA       NA       NA       NA
BCF4...............................       NA       NA       NA       NA       NA       NA       NA       NA    0.015       NA       NA       NA       NA
BCF6...............................       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA
BC3F8..............................       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                In situ thermal cleaning:
--------------------------------------------------------------------------------------------------------------------------------------------------------
1-Ui...............................       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA
BCF4...............................       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA
BC2F6..............................       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA
BC3F8..............................       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA       NA
--------------------------------------------------------------------------------------------------------------------------------------------------------
Notes: NA = Not applicable; i.e., there are no applicable default emission factor measurements for this gas. This does not necessarily imply that a
  particular gas is not used in or emitted from a particular process sub-type or process type.

Subpart N--Glass Production

0
27. Section 98.144 is amended by revising paragraphs (b), (c), and (d)
to read as follows:

Sec.  98.144  Monitoring and QA/QC requirements.

* * * * *
    (b) Unless you use the default value of 1.0, you must measure
carbonate-based mineral mass fractions at least annually to verify the
mass fraction data provided by the supplier of the raw material; such
measurements shall be based on sampling and chemical analysis using
consensus standards that specify X-ray fluorescence. For measurements
made in years prior to the emissions reporting year 2014, you may also
use ASTM D3682-01 (Reapproved 2006) Standard Test Method for Major and
Minor Elements in Combustion Residues from Coal Utilization Processes
(incorporated by reference, see Sec.  98.7) or ASTM D6349-09 Standard
Test Method for Determination of Major and Minor Elements in Coal,
Coke, and Solid Residues from Combustion of Coal and Coke by
Inductively Coupled Plasma--Atomic Emission Spectrometry (incorporated
by reference, see Sec.  98.7).
    (c) Unless you use the default value of 1.0, you must determine the
annual average mass fraction for the carbonate-based mineral in each
carbonate-based raw material by calculating an arithmetic average of
the monthly data obtained from raw material suppliers or sampling and
chemical analysis.
    (d) Unless you use the default value of 1.0, you must determine on
an annual basis the calcination fraction for each carbonate consumed
based on sampling and chemical analysis using an industry consensus
standard. If performed, this chemical analysis must be conducted using
an x-ray fluorescence test or other enhanced testing method published
by an industry consensus standards organization (e.g., ASTM, ASME, API,
etc.).
0
28. Section 98.146 is amended by revising paragraphs (b)(5)
introductory text and (b)(7) to read as follows:

Sec.  98.146  Data reporting requirements.

* * * * *
    (b) * * *
    (5) Results of all tests, if applicable, used to verify the
carbonate-based mineral mass fraction for each carbonate-based raw
material charged to a continuous glass melting furnace, as specified in
paragraphs (b)(5)(i) through (iii) of this section.
* * * * *
    (7) Method used to determine decimal fraction of calcination,
unless you used the default value of 1.0.
* * * * *
0
29. Section 98.147 is amended by revising paragraphs (b)(3), (b)(4)
introductory text, (d)(2), and (d)(3) to read as follows:

Sec.  98.147  Records that must be retained.

* * * * *
    (b) * * *
    (3) Data on carbonate-based mineral mass fractions provided by the
raw material supplier for all raw materials consumed annually and
included in calculating process emissions in Equation N-1 of this
subpart, if applicable.
    (4) Results of all tests, if applicable, used to verify the
carbonate-based mineral mass fraction for each carbonate-based raw
material charged to a continuous glass melting furnace, including the
data specified in paragraphs (b)(4)(i) through (v) of this section.
* * * * *
    (d) * * *
    (2) Annual amount of each carbonate-based raw material charged to
each continuous glass melting furnace (tons) (Equation N-1 of this
subpart).
    (3) Decimal fraction of calcination achieved for each carbonate-
based raw material for each continuous glass melting furnace (specify
the default value, if used, or the value determined according to Sec.
98.144) (percentage, expressed as a decimal) (Equation N-1 of this
subpart).

Subpart O--HCFC-22 Production and HFC-23 Destruction

0
30. Section 98.156 is amended by revising paragraphs (a) introductory
text and (d) to read as follows:

Sec.  98.156  Data reporting requirements.

    (a) In addition to the information required by Sec.  98.3(c), the
HCFC-22 production facility shall report the following information for
each HCFC-22 production process:
* * * * *
    (d) If the HFC-23 concentration measured pursuant to Sec.
98.154(l) is greater than that measured during the performance test
that is the basis for the destruction efficiency (DE), the facility
shall report the method used to calculate the revised destruction
efficiency, specifying whether

Sec.  98.154(l)(1) or (2) has been used for the calculation.
* * * * *

Subpart P--Hydrogen Production

0
31. Section 98.163 is amended by revising parameter ``CO2''
of Equation P-3 in paragraph (b)(3) to read as follows:

Sec.  98.163  Calculating GHG emissions.

* * * * *
    (b) * * *
    (3) * * *
* * * * *
CO2 = Annual CO2 emissions from fuel and
feedstock consumption (metric tons/yr).
* * * * *
0
32. Section 98.164 is amended by revising paragraph (b)(1) to read as
follows:

Sec.  98.164  Monitoring and QA/QC requirements.

* * * * *
    (b) * * *
    (1) Calibrate all oil and gas flow meters that are used to measure
liquid and gaseous fuel and feedstock volumes (except for gas billing
meters) according to the monitoring and QA/QC requirements for the Tier
3 methodology in Sec.  98.34(b)(1). Perform oil tank drop measurements
(if used to quantify liquid fuel or feedstock consumption) according to
Sec.  98.34(b)(2). Calibrate all solids weighing equipment according to
the procedures in Sec.  98.3(i).
* * * * *
0
33. Section 98.166 is amended by revising paragraphs (b)(4), (d), and
(e) to read as follows:

Sec.  98.166  Data reporting requirements.

* * * * *
    (b) * * *
    (4) Annual quantity of ammonia intentionally produced as a desired
product, if applicable (metric tons).
* * * * *
    (d) Annual quantity of carbon other than CO2 collected
and transferred off site in either gas, liquid, or solid forms (kg
carbon), excluding methanol.
    (e) Annual quantity of methanol intentionally produced as a desired
product, if applicable, (metric tons) for each process unit.

Subpart Q--Iron and Steel Production

0
34. Section 98.173 is amended by revising Equation Q-5 in paragraph
(b)(1)(v) to read as follows:

Sec.  98.173  Calculating GHG emissions.

* * * * *
    (b) * * *
    (1) * * *
    (v) * * *
    [GRAPHIC] [TIFF OMITTED] TP15JA16.003

* * * * *
0
35. Section 98.176 is amended by revising Equation Q-10 in paragraph
(e)(6)(ii), Equation Q-11 in paragraph (e)(6)(iii), Equation Q-12 in
paragraph (e)(6)(iv), and the parameter ``n'' of Equation Q-12 in
paragraph (e)(6)(iv) to read as follows:

Sec.  98.176  Data reporting requirements.

* * * * *
    (e) * * *
    (6) * * *
    (ii) * * *
    [GRAPHIC] [TIFF OMITTED] TP15JA16.004

* * * * *
    (iii) * * *
    [GRAPHIC] [TIFF OMITTED] TP15JA16.005

* * * * *
    (iv) * * *
    [GRAPHIC] [TIFF OMITTED] TP15JA16.006

* * * * *
n = Number of gaseous, liquid, and solid fuel inputs to each process
unit as used in Equation Q-9 of this subpart.
* * * * *

Subpart S--Lime Manufacturing

0
36. Section 98.196 is amended by revising paragraph (b) introductory
text and adding paragraphs (b)(19) through (21) to read as follows:

Sec.  98.196  Data reporting requirements.

* * * * *
    (b) If a CEMS is not used to measure CO2 emissions, then
you must report the information listed in paragraphs (b)(1) through
(21) of this section.
* * * * *
    (19) Annual emission factors for each lime product type produced.
    (20) Annual emission factors for each calcined byproduct/waste by
lime type that is sold.
    (21) Annual average results of chemical composition analysis of
each type of lime product produced and calcined byproduct/waste sold.

Subpart U--Miscellaneous Uses of Carbonate

0
37. Section 98.216 is amended by revising paragraph (e) introductory
text to read as follows:

Sec.  98.216  Data reporting requirements.

* * * * *
    (e) If you followed the calculation method of Sec.  98.213(a), you
must report the information in paragraphs (e)(1) through (3) of this
section.
* * * * *

Subpart V--Nitric Acid Production

0
38. Section 98.220 is revised to read as follows:

Sec.  98.220  Definition of source category.

    A nitric acid production facility uses one or more trains to
produce nitric acid. A nitric acid train produces nitric acid through
the catalytic oxidation of ammonia.
0
39. Section 98.223 is amended by revising paragraph (a)(2) to read as
follows:

Sec.  98.223  Calculating GHG emissions.

    (a) * * *
    (2) Request Administrator approval for an alternative method of
determining N2O emissions according to paragraphs (a)(2)(i)
through (iv) of this section.
    (i) If you received Administrator approval for an alternative
method of determining N2O emissions in the previous
reporting year and your methodology is unchanged, your alternative
method is automatically approved for the next reporting year.
    (ii) You must notify the EPA of your use of a previously approved
alternative method in your annual report.
    (iii) Otherwise, if you have not received Administrator approval
for an alternative method of determining N2O emissions in a
prior reporting year or your methodology has changed, you must submit
the request within the first 30 days of each subsequent reporting year.
    (iv) If the Administrator does not approve your requested
alternative method within 150 days of the end of the reporting year,
you must determine the N2O emissions for the current
reporting period using the procedures specified in paragraph (a)(1) of
this section.
* * * * *
0
40. Section 98.226 is amended by revising paragraph (h) to read as
follows:

Sec.  98.226  Data reporting requirements.

* * * * *
    (h) Abatement technologies used (if applicable) and date of
installation of abatement technology.
* * * * *

Subpart X--Petrochemical Production

0
41. Section 98.240 is amended by revising paragraph (a) to read as
follows:

Sec.  98.240  Definition of the source category.

    (a) The petrochemical production source category consists of
processes as described in paragraphs (a)(1) through (3) of this
section.
    (1) The petrochemical production source category consists of all
processes that produce acrylonitrile, carbon black, ethylene, ethylene
dichloride, ethylene oxide, or methanol, except as specified in
paragraphs (b) through (g) of this section.
    (2) The petrochemical production source category includes processes
that produce the petrochemical as an intermediate in the on-site
production of other chemicals as well as processes that produce the
petrochemical as an end product for sale or shipment off site.
    (3) When ethylene dichloride and vinyl chloride monomer are
produced in an integrated process, you may consider the entire
integrated process to be the petrochemical process for the purpose of
complying with the mass balance option in Sec.  98.243(c). If you elect
to consider the integrated process to be the petrochemical process,
then the mass balance must be performed over the entire integrated
process.
* * * * *
0
42. Section 98.243 is amended by revising paragraphs (c)(3), (c)(4)
introductory text, and (c)(4)(i) to read as follows:

Sec.  98.243  Calculating GHG emissions.

* * * * *
    (c) * * *
    (3) Collect a sample of each feedstock and product at least once
per month and determine the molecular weight (for gaseous materials
when the quantity is measured in scf) and carbon content of each sample
according to the procedures of Sec.  98.244(b)(4). If multiple valid
molecular weight or carbon content measurements are made during the
monthly measurement period, average them arithmetically. However, if a
particular liquid or solid feedstock is delivered in lots, and if
multiple deliveries of the same feedstock are received from the same
supply source in a given calendar month, only one representative sample
is required. Alternatively, you may use the results of analyses
conducted by a feedstock supplier, or product customer, provided the
sampling and analysis is conducted at least once per month using any of
the procedures specified in Sec.  98.244(b)(4).
    (4) If you determine that the monthly average concentration of a
specific compound in a feedstock or product is greater than 99.5
percent by volume or mass, then as an alternative to the sampling and
analysis specified in paragraph (c)(3) of this section, you may
determine molecular weight and carbon content in accordance with
paragraphs (c)(4)(i) through (iii) of this section.
    (i) Calculate the molecular weight and carbon content assuming 100
percent of that feedstock or product is the specific compound.
* * * * *
0
43. Section 98.246 is amended by:
0
a. Revising paragraphs (a)(5), (a)(6)(ii), and (a)(6)(iii);
0
b. Adding paragraphs (a)(14) and (15); and
0
c. Revising paragraphs (b)(2), (3), and (8).
    The revisions and additions read as follows:

Sec.  98.246  Data reporting requirements.

* * * * *
    (a) * * *
    (5) Annual quantity of each type of petrochemical produced from
each process unit (metric tons). If your petrochemical process is an
integrated ethylene dichloride and vinyl chloride monomer process,
report either the measured ethylene dichloride production (metric tons)
or both the measured quantity of vinyl chloride monomer production
(metric tons) and an estimate of the ethylene dichloride production
(metric tons).
    (6) * * *
    (ii) Description of each type of measurement device (e.g., flow
meter, weighing device) used to determine volume or mass in accordance
with Sec.  98.244(b)(1) through (3).
    (iii) Identification of each method (i.e., method number, title, or
other description) used to determine volume or mass in accordance with
Sec.  98.244(b)(1) through (3).
* * * * *
    (14) Annual average of the measurements of the carbon content of
each feedstock and product.
    (i) For feedstocks and products that are gaseous or solid, report
this quantity in kg carbon per kg of feedstock or product.
    (ii) For liquid feedstocks and products, report this quantity
either in units of kg carbon per kg of feedstock or production, or kg C
per gallon of feedstock or product.

    (15) For each gaseous feedstock and product, the annual average of
the measurements of molecular weight in units of kg per kg mole.
    (b) * * *
    (2) For CEMS used on stacks that include emissions from stationary
combustion units that burn any amount of off-gas from the petrochemical
process, report the relevant information required under Sec.
98.36(c)(2) and (e)(2)(vi) for the Tier 4 calculation methodology.
Section 98.36(c)(2)(ii), (ix) and (x) does not apply for the purposes
of this subpart.
    (3) For CEMS used on stacks that do not include emissions from
stationary combustion units, report the information required under
Sec.  98.36(b)(6), (b)(7), (b)(9)(i), (b)(9)(ii) and (e)(2)(vi).
* * * * *
    (8) Annual quantity of each type of petrochemical produced from
each process unit (metric tons). If your petrochemical process is an
integrated ethylene dichloride and vinyl chloride monomer process,
report either the measured ethylene dichloride production (metric tons)
or both the measured quantity of vinyl chloride monomer production
(metric tons) and an estimate of the ethylene dichloride product
(metric tons).
* * * * *
0
44. Section 98.247 is amended by revising paragraph (a) to read as
follows:

Sec.  98.247  Records that must be retained.

* * * * *
    (a) If you comply with the CEMS measurement methodology in Sec.
98.243(b), then you must retain under this subpart the records required
for the Tier 4 Calculation Methodology in Sec.  98.37, records of the
procedures used to develop estimates of the fraction of total emissions
attributable to petrochemical processing and combustion of
petrochemical process off-gas as required in Sec.  98.246(b), and
records of any annual average HHV calculations.
* * * * *
0
45. Section 98.248 is amended by revising the definition for
``Product'' to read as follows:

Sec.  98.248  Definitions.

* * * * *
    Product means each of the following carbon-containing outputs from
a process: the petrochemical, recovered byproducts, and liquid organic
wastes that are not combusted onsite. Product does not include process
vent emissions, fugitive emissions, or wastewater.

Subpart Y--Petroleum Refineries

0
46. Section 98.253 is amended by:
0
a. Revising paragraphs (b) introductory text, (b)(1)(iii)(B), (h)(1)
introductory text, and (h)(2) introductory text;
0
b. Revising parameters ``0.98'' of Equations Y-16a and Y-16b and
``0.02'' of Equation Y-17 in paragraph (h)(2); and
0
c. Revising paragraph (i) and paragraph (j) introductory text.
    The revisions read as follows:

Sec.  98.253  Calculating GHG emissions.

* * * * *
    (b) For flares, calculate GHG emissions according to the
requirements in paragraphs (b)(1) through (3) of this section. All gas
discharged through the flare stack must be considered for the flare GHG
emissions calculations with the exception of gas used for the flare
pilots, which may be excluded.
    (1) * * *
    (iii) * * *
    (B) For periods of normal operation, use the average higher heating
value measured for the fuel gas used as flare sweep or purge gas for
the higher heating value of the flare gas. If higher heating value of
the fuel gas is not measured, the higher heating value of the flare gas
under normal operations may be estimated from historic data or
engineering calculations.
* * * * *
    (h) * * *
    (1) For uncontrolled asphalt blowing operations or asphalt blowing
operations controlled either by vapor scrubbing or by another non-
combustion control device, calculate CO2 and CH4
emissions using Equations Y-14 and Y-15 of this section, respectively.
* * * * *
    (2) For asphalt blowing operations controlled by either a thermal
oxidizer, a flare, or other vapor combustion control device, calculate
CO2 using either Equation Y-16a or Equation Y-16b of this
section and calculate CH4 emissions using Equation Y-17 of
this section, provided these emissions are not already included in the
flare emissions calculated in paragraph (b) of this section or in the
stationary combustion unit emissions required under subpart C of this
part (General Stationary Fuel Combustion Sources).
* * * * *

(Eq. Y-16a) * * *
* * * * *
0.98 = Assumed combustion efficiency of the control device.
* * * * *

(Eq. Y-16b) * * *
* * * * *
0.98 = Assumed combustion efficiency of the control device.
* * * * *

(Eq. Y-17) * * *
* * * * *
0.02 = Fraction of methane uncombusted in the controlled stream based
on assumed 98% combustion efficiency.
* * * * *
    (i) For each delayed coking unit, calculate the CH4
emissions from delayed decoking operations (venting, draining,
deheading, and coke-cutting) according to the requirements in
paragraphs (i)(1) through (5) of this section.
    (1) Determine the typical dry mass of coke produced per cycle from
company records of the mass of coke produced by the delayed coking
unit. Alternatively, you may estimate the typical dry mass of coke
produced per cycle based on the delayed coking unit vessel (coke drum)
dimensions and typical coke drum outage at the end of the coking cycle
using Equation Y-18a of this section.
[GRAPHIC] [TIFF OMITTED] TP15JA16.007

Where:

Mcoke = Typical dry mass of coke in the delayed coking
unit vessel at the end of the coking cycle (metric tons/cycle).
[rho]bulk = Bulk coke bed density (metric tons per cubic
feet; mt/ft3). Use the default value of 0.0191 mt/ft3.
Hdrum = Internal height of delayed coking unit vessel
(feet).
Houtage = Typical distance from the top of the delayed
coking unit vessel to the top of the coke bed (i.e., coke drum
outage) at the end of the coking cycle (feet) from

company records or engineering estimates.
D = Diameter of delayed coking unit vessel (feet).

    (2) Determine the typical mass of water in the delayed coking unit
vessel at the end of the cooling cycle prior to venting to the
atmosphere using Equation Y-18b of this section.
[GRAPHIC] [TIFF OMITTED] TP15JA16.008

Where:

Mwater = Mass of water in the delayed coking unit vessel
at the end of the cooling cycle just prior to atmospheric venting
(metric tons/cycle).
[rho]water = Density of water at average temperature of
the delayed coking unit vessel at the end of the cooling cycle just
prior to atmospheric venting (metric tons per cubic feet; mt/ft3).
Use the default value of 0.0270 mt/ft3.
Hwater = Typical distance from the bottom of the coking
unit vessel to the top of the water level at the end of the cooling
cycle just prior to atmospheric venting (feet) from company records
or engineering estimates.
Mcoke = Typical dry mass of coke in the delayed coking
unit vessel at the end of the coking cycle (metric tons/cycle) as
determined in paragraph (i)(1) of this section.
[rho]particle = Particle density of coke (metric tons per
cubic feet; mt/ft3). Use the default value of 0.0382 mt/ft3.
D = Diameter of delayed coking unit vessel (feet).

    (3) Determine the average temperature of the delayed coking unit
vessel when the drum is first vented to the atmosphere using either
Equation Y-18c or Y-18d of this section, as appropriate, based on the
measurement system available.
[GRAPHIC] [TIFF OMITTED] TP15JA16.009

Where:

Tinitial = Average temperature of the delayed coking unit
vessel when the drum is first vented to the atmosphere ([deg]F).
Toverhead = Temperature of the delayed coking unit vessel
overhead line measured as near the coking unit vessel as practical
just prior to venting to the atmosphere. If the temperature of the
delayed coking unit vessel overhead line is less than
216[emsp14][deg]F, use Toverhead = 216[emsp14][deg]F.
Tbottom = Temperature of the delayed coking unit vessel
near the bottom of the coke bed. If the temperature at the bottom of
the coke bed is less than 212[emsp14][deg]F, use Tbottom
= 212[emsp14][deg]F.
[GRAPHIC] [TIFF OMITTED] TP15JA16.010

Where:

Tinitial = Average temperature of the delayed coking unit
vessel when the drum is first vented to the atmosphere ([deg]F).
Poverhead = Pressure of the delayed coking unit vessel
just prior to opening the atmospheric vent (pounds per square inch
gauge, psig).

(4) Determine the typical mass of steam generated and released per
decoking cycle using Equation Y-18e of this section.
[GRAPHIC] [TIFF OMITTED] TP15JA16.011

Where:

Msteam = Mass of steam generated and released per
decoking cycle (metric tons/cycle).
fConvLoss = fraction of total heat loss that is due to
convective heat loss from the sides of the coke vessel (unitless).
Use the default value of 0.10.
Mwater = Mass of water in the delayed coking unit vessel
at the end of the cooling cycle just prior to atmospheric venting
(metric tons/cycle).
Cp,water = Heat capacity of water (British thermal units
per metric ton per degree Fahrenheit; Btu/mt-[deg]F). Use the
default value of 2,205 Btu/mt-[deg]F.
Mcoke = Typical dry mass of coke in the delayed coking
unit vessel at the end of the coking cycle (metric tons/cycle) as
determined in paragraph (i)(1) of this section.
Cp,coke = Heat capacity of petroleum coke (Btu/mt-
[deg]F). Use the default value of 584 Btu/mt-[deg]F.
Tinitial = Average temperature of the delayed coking unit
vessel when the drum is first vented to the atmosphere ([deg]F) as
determined in paragraph (i)(3) of this section.
Tfinal = Temperature of the delayed coking unit vessel
when steam generation stops ([deg]F). Use the default value of
212[emsp14][deg]F.
[Delta]Hvap = Heat of vaporization of water (British
thermal units per metric ton; Btu/mt). Use the default value of
2,116,000 Btu/mt.

(5) Calculate the CH4 emissions from decoking operations at
each delayed coking unit using Equation Y-18f of this section.
[GRAPHIC] [TIFF OMITTED] TP15JA16.012

Where:

CH4 = Annual methane emissions from the delayed coking
unit decoking operations (metric ton/year).
Msteam = Mass of steam generated and released per
decoking cycle (metric tons/cycle) as determined in paragraph (i)(3)
of this section.
EmFDCU = Methane emission factor for delayed coking unit
(kilograms CH4 per metric ton of steam; kg
CH4/mt steam) from unit-specific measurement data. If you
do not have unit-specific measurement data, use the default value of
7.9 kg CH4/metric ton steam.
N = Cumulative number of decoking cycles (or coke-cutting cycles)
for all delayed coking unit vessels associated with the delayed
coking unit during the year.
0.001 = Conversion factor (metric ton/kg).

    (j) For each process vent not covered in paragraphs (a) through (i)
of this section that can reasonably be expected to contain greater than
2 percent by volume CO2 or greater than 0.5 percent by
volume of CH4 or greater than 0.01 percent by volume (100
parts per million) of N2O, calculate GHG emissions using Equation Y-19
of this section. You must also use Equation Y-19 of this section to
calculate CH4 emissions for catalytic reforming unit
depressurization and purge vents when methane is used as the purge gas,
and CO2 and/or CH4 emissions, as applicable, if
you elected this method as an alternative to the methods in paragraphs
(f), (h), or (k) of this section.
* * * * *
0
47. Section 98.254 is amended by revising paragraph (j), redesignating
paragraph (k) as paragraph (l), and adding new paragraph (k) to read as
follows:

Sec.  98.254  Monitoring and QA/QC requirements.

* * * * *
    (j) Determine the quantity of petroleum process streams using
company records. These quantities include the quantity of coke produced
per cycle, asphalt blown, quantity of crude oil plus the quantity of
intermediate products received from off site, and the quantity of
unstabilized crude oil received at the facility.
    (k) Determine temperature or pressure of delayed coking unit vessel
using process instrumentation operated, maintained, and calibrated
according to the manufacturer's instructions.
* * * * *
0
48. Section 98.256 is amended by revising paragraphs (e)(3) and (6),
(h)(5)(ii)(A), and (k) to read as follows:

Sec.  98.256  Data reporting requirements.

* * * * *
    (e) * * *
    (3) A description of the flare service (general facility flare,
unit flare, emergency only or back-up flare) and an indication of
whether or not the flare is serviced by a flare gas recovery system.
* * * * *
    (6) If you use Equation Y-1a in Sec.  98.253, an indication of
whether daily or weekly measurement periods are used, annual average
carbon content of the flare gas (in kg carbon per kg flare gas), and,
either the annual volume of flare gas combusted (in scf/year) and the
annual average molecular weight (in kg/kg-mole), or, the annual mass of
flare gas combusted (in kg/yr).
* * * * *
    (h) * * *
    (5) * * *
    (ii) * * *
    (A) The annual volume of recycled tail gas (in scf/year).
* * * * *
    (k) For each delayed coking unit, the owner or operator shall
report:
    (1) The unit ID number (if applicable).
    (2) Maximum rated throughput of the unit, in bbl/stream day.
    (3) Annual quantity of coke produced in the unit during the
reporting year, in metric tons.
    (4) The calculated annual CH4 emissions (in metric tons
of CH4) for the delayed coking unit.
    (5) The total number of delayed coking vessels (or coke drums)
associated with the delayed coking unit.
    (6) The basis for the typical dry mass of coke in the delayed
coking unit vessel at the end of the coking cycle (mass measurements
from company records or calculated using Equation Y-18a of this
subpart).
    (7) An indication of the method used to estimate the average
temperature of the coke bed, Tinitial (overhead temperature
and Equation Y-18c of this subpart or pressure correlation and Equation
Y-18d of this subpart).
    (8) An indication of whether a unit-specific methane emissions
factor or the default methane emission factor was used for the delayed
coking unit.
* * * * *
0
49. Section 98.257 is amended by:
0
a. Revising paragraphs (b) introductory text and (b)(41) through (45);
0
b. Removing paragraph (b)(46)
0
c. Redesignating paragraphs (b)(47) through (67) as paragraphs (b)(53)
through (73);
0
d. Adding new paragraphs (b)(46) through (52); and
0
e. Revising newly redesignated paragraph (b)(65).
    The revisions and additions read as follows:

Sec.  98.257  Records that must be retained.

* * * * *
    (b) Verification software records. You must keep a record of the
file generated by the verification software specified in Sec.  98.5(b)
for the applicable data specified in paragraphs (b)(1) through (73) of
this section. Retention of this file satisfies the recordkeeping
requirement for the data in paragraphs (b)(1) through (73) of this
section.
* * * * *
    (41) Typical dry mass of coke in the delayed coking unit vessel at
the end of the coking cycle (metric tons/cycle) from company records or
calculated using Equation Y-18a of this subpart (Equations Y-18a, Y-18b
and Y-18e in Sec.  98.253) for each delayed coking unit.
    (42) Internal height of delayed coking unit vessel (feet) (Equation
Y-18a in Sec.  98.253) for each delayed coking unit.
    (43) Typical distance from the top of the delayed coking unit
vessel to the top of the coke bed (i.e., coke drum outage) at the end
of the coking cycle (feet) from company records or engineering
estimates (Equation Y-18a in Sec.  98.253) for each delayed coking
unit.
    (44) Diameter of delayed coking unit vessel (feet) (Equations Y-18a
and Y-18b in Sec.  98.253) for each delayed coking unit.
    (45) Mass of water in the delayed coking unit vessel at the end of
the cooling cycle prior to atmospheric venting (metric ton/cycle)
(Equations Y-18b and Y-18e in Sec.  98.253) for each delayed coking
unit.
    (46) Typical distance from the bottom of the coking unit vessel to
the top of the water level at the end of the cooling cycle just prior
to atmospheric venting (feet) from company records or engineering
estimates (Equation Y-18b in Sec.  98.253) for each delayed coking
unit.
    (47) Mass of steam generated and released per decoking cycle
(metric tons/cycle) (Equations Y-18e and Y-18f in Sec.  98.253) for
each delayed coking unit.
    (48) Average temperature of the delayed coking unit vessel when the
drum is first vented to the atmosphere ([deg]F) (Equations Y-18c, Y-
18d, and Y-18e in Sec.  98.253) for each delayed coking unit.
    (49) Temperature of the delayed coking unit vessel overhead line
measured as near the coking unit vessel as practical just prior to
venting the atmosphere (Equation Y-18c in Sec.  98.253) for each
delayed coking unit.
    (50) Pressure of the delayed coking unit vessel just prior to
opening the atmospheric vent (psig) (Equation Y-18d in Sec.  98.253)
for each delayed coking unit.

    (51) Methane emission factor for delayed coking unit (kilograms
CH4 per metric ton of steam; kg CH4/mt steam)
(Equation Y-18f in Sec.  98.253) for each delayed coking unit.
    (52) Cumulative number of decoking cycles (or coke-cutting cycles)
for all delayed coking unit vessels associated with the delayed coking
unit during the year (Equation Y-18f in Sec.  98.253) for each delayed
coking unit.
* * * * *
    (65) Specify whether the calculated or default loading factor L
specified in Sec.  98.253(n) is entered, for each liquid loaded to each
vessel (methods specified in Sec.  98.253(n)).
* * * * *

Subpart Z--Phosphoric Acid Production

0
50. Section 98.266 is amended by revising paragraph (f)(3) to read as
follows:

Sec.  98.266  Data reporting requirements.

* * * * *
    (f) * * *
    (3) Annual phosphoric acid production capacity (tons) for each wet-
process phosphoric acid process line.
* * * * *

Subpart AA--Pulp and Paper Manufacturing

0
51. Section 98.273 is amended by revising paragraphs (a)(1), (b)(1),
and (c)(1) to read as follows:

Sec.  98.273  Calculating GHG emissions.

    (a) * * *
    (1) Calculate fossil fuel-based CO2 emissions from
direct measurement of fossil fuels consumed and default emissions
factors according to the Tier 1 methodology for stationary combustion
sources in Sec.  98.33(a)(1). Tiers 2 or 3 from Sec.  98.33(a)(2) or
(3) may be used to calculate fossil fuel-based CO2 emissions
if the respective monitoring and QA/QC requirements described in Sec.
98.34 are met.
* * * * *
    (b) * * *
    (1) Calculate fossil CO2 emissions from fossil fuels
from direct measurement of fossil fuels consumed and default emissions
factors according to the Tier 1 Calculation Methodology for stationary
combustion sources in Sec.  98.33(a)(1). Tiers 2 or 3 from Sec.
98.33(a)(2) or (3) may be used to calculate fossil fuel-based
CO2 emissions if the respective monitoring and QA/QC
requirements described in Sec.  98.34 are met.
* * * * *
    (c) * * *
    (1) Calculate CO2 emissions from fossil fuel from direct
measurement of fossil fuels consumed and default HHV and default
emissions factors, according to the Tier 1 Calculation Methodology for
stationary combustion sources in Sec.  98.33(a)(1). Tiers 2 or 3 from
Sec.  98.33(a)(2) or (3) may be used to calculate fossil fuel-based
CO2 emissions if the respective monitoring and QA/QC
requirements described in Sec.  98.34 are met.
* * * * *
0
52. Section 98.275 is amended by revising paragraph (b) to read as
follows:

Sec.  98.275  Procedures for estimating missing data.

* * * * *
    (b) For missing measurements of the mass of spent liquor solids or
spent pulping liquor flow rates, use the lesser value of either the
maximum mass or fuel flow rate for the combustion unit, or the maximum
mass or flow rate that the fuel meter can measure. Alternatively,
records of the daily spent liquor solids firing rate obtained to comply
with Sec.  63.866(c)(1) of this chapter may be used, adjusting for the
duration of the missing measurements, as appropriate.
* * * * *
0
53. Table AA-2 to Subpart AA of Part 98 is amended by:
0
a. Revising the column headings for ``Kraft lime kilns'' and ``Kraft
calciners'';
0
b. Revising the entry for ``Petroleum coke''; and
0
c. Revising the footnotes.
    The revisions read as follows:

       Table AA-2 to Subpart AA of Part 98--Kraft Lime Kiln and Calciner Emissions Factors for CH4 and N2O
----------------------------------------------------------------------------------------------------------------
                                                      Fossil fuel-based emissions factors (kg/mmBtu HHV)
                                             -------------------------------------------------------------------
                    Fuel                           Kraft rotary lime kilns             Kraft calciners \a\
                                             -------------------------------------------------------------------
                                                    CH4              N2O              CH4              N2O
----------------------------------------------------------------------------------------------------------------

                                                  * * * * * * *
Petroleum coke..............................          0.0027                0           \b\ NA           \b\ NA

                                                  * * * * * * *
----------------------------------------------------------------------------------------------------------------
\a\ Includes, for example, fluidized bed calciners at kraft mills.
\b\ Emission factors for kraft calciners are not available.

Subpart CC--Soda Ash Manufacturing

0
54. Section 98.294 is amended by revising paragraph (a)(2) to read as
follows:

Sec.  98.294  Monitoring and QA/QC requirements.

* * * * *
    (a) * * *
    (2) Measure the mass of trona input to each soda ash manufacturing
line on a monthly basis using belt scales or methods used for
accounting purposes.
* * * * *
0
55. Section 98.296 is amended by revising paragraph (a)(1) and adding
paragraph (b)(5) to read as follows:

Sec.  98.296  Data reporting requirements.

* * * * *
    (a) * * *
    (1) Annual consumption of trona or liquid alkaline feedstock at the
facility level (tons).
* * * * *
    (b) * * *
    (5) Annual consumption of trona or liquid alkaline feedstock at the
facility level (tons).
* * * * *

Subpart DD--Electrical Transmission and Distribution Equipment Use

0
56. Section 98.306 is amended by revising paragraphs (a)(2) and (3) and
adding paragraphs (a)(4), (a)(5), (m), and (n) to read as follows:

Sec.  98.306  Data reporting requirements.

* * * * *
    (a) * * *
    (2) New hermetically sealed-pressure switchgear during the year.
    (3) New SF6- or PFC-insulated equipment other than
hermetically sealed-pressure switchgear during the year.
    (4) Retired hermetically sealed-pressure switchgear during the
year.
    (5) Retired SF6- or PFC-insulated equipment other than
hermetically sealed-pressure switchgear during the year.
* * * * *
    (m) State(s) or territory in which the facility lies and total
miles of transmission and distribution lines located within each state
or territory.
    (n) The following numbers of pieces of equipment:
    (1) New hermetically sealed-pressure switchgear during the year.
    (2) New SF6- or PFC-insulated equipment other than
hermetically sealed-pressure switchgear during the year.
    (3) Retired hermetically sealed-pressure switchgear during the
year.
    (4) Retired SF6- or PFC-insulated equipment other than
hermetically sealed-pressure switchgear during the year.

Subpart FF--Underground Coal Mines

0
57. Section 98.323 is amended by:
0
a. Revising parameter ``n'' of Equation FF-1 in paragraph (a);
0
b. Revising paragraph (a)(1) introductory text and paragraph (a)(2);
0
c. Revising parameter ``CH4D'' and ``n'' of Equation FF-3 in
paragraph (b); and
0
d. Revising paragraph (b)(1) and paragraph (b)(2) introductory text.
    The revisions and additions read as follows:

Sec.  98.323  Calculating GHG emissions.

    (a) * * *
* * * * *
n = The number of days in the quarter where active ventilation of
mining operations is taking place at the monitoring point. To obtain
the number of days in the quarter, divide the total number of hours
in the quarter where active ventilation is taking place by 24 hours
per day.
* * * * *
    (1) The quarterly periods are:
* * * * *
    (2) Values of V, C, T, P, and, if applicable, (fH2O),
must be based on measurements taken at least once each quarter with no
fewer than 6 weeks between measurements. If measurements are taken more
frequently than once per quarter, then use the average value for all
measurements taken that quarter. If continuous measurements are taken,
then use the average value over the time period of continuous
monitoring.
* * * * *
    (b) * * *
* * * * *
CH4D = Weekly CH4 liberated from the
monitoring point (metric tons CH4).
* * * * *
n = The number of days in the week that the system is operational at