### 1 

## MEMORANDUM

FROM: Rachel Schmeltz

, Lisa Grogan

- McCulloch, U.S. EPA, Climate Change Division

TO : Docket EPA

- HQ

- OAR

- 2015

- 0526

DATE: December 1 1 , 2015

SUBJECT: Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

1.0 INTRODUCTION

The 2009 f inal GHG reporting rule (2009 final rule) was signed by EPA Administrator Lisa Jackson on September 22, 2009 and published in the Federal Register on October 30, 200 9 (74 FR 56260, October 30, 2009). The 2009 f inal rule , which became effective on December 29, 2009, included reporting of GHGs from various facilities and suppliers, consistent with the 2008 Consolidated Appropriations Act. Subsequent notices were publi shed in 2010 finalizing the requirements for s ubparts T, FF , II, and TT (75 FR 39736 , July 12, 2010 ) , subpart W (75 FR 74458, November 20, 2010), subparts I, L, DD, QQ, and SS (75 FR 74774, December 1, 2010), and subparts RR and UU (75 FR 75060, December 1 , 2010). These requirements are contained in 40 CFR part 98. The rule does not require control of GHGs, rather it only requires that sources above certain threshold levels monitor and report emissions and other related data. Following the promulgation of t hese subparts, the EPA has finalized several technical and clarifying amendments to these and other subparts under the Greenhouse Gas Reporting Program (GHGRP).

The EPA is proposing to amend specific provisions of the GHG reporting rule to continue to improve the GHGRP and address issues identified during implementation. The proposed changes are intended to streamline implementation of the rule, improve the quality and consistency of the data collected under the rule, update provisions to more accur ately reflect industry processes and emissions, and implement corrections for minor editorial or reference errors or clarifications to existing requirements.

The purpose of this memorandum is to provide a detailed list of each change proposed in

this acti on

. The table in section 3.0 contains a list of each change proposed, the rule language for the current requirement, and the proposed language. A brief explanation of the reason for the change is included for those items that are not specifically addresse d in the preamble for this proposal. These changes are minor clarifications of the requirements text to better reflect EPA’s intent, simple corrections to calculation terms or cross

- references that do not revise the output of the calculations, harmonizing changes within a subpart (such as changes to terminology), simple

### 2 

## editorial and minor error corrections, or removal of redundant text. Also available in the docket

for this action is a set of documents in redline strikeout format for each section of Part 98 for which EPA is proposing changes.

2.0 SUMMARY OF CHANGES INCLUDED

EPA is proposing changes to Part 98 for the subparts identified in the table below. Significant changes that are not detailed in this memorandum include changes to tables for

seve ral subparts. The amended tables are available in the redline document for the individual subpart and as attachments to this memorandum. Tables that have been changed include: Table

A

- 3, A

- 4, A

- 5, C

- 1, C

- 2, AA

- 2, HH

- 3, HH

- 4, NN

- 2, and TT

- 1.

Subpart

A

– General Provision

C

– General Stationary Fuel Combustion Sources

E

– Adipic Acid Production

F

– Aluminum Production

G

– Ammonia Manufacturing

I

– Electronics Manufacturing

N

– Glass Production

O

– HCFC

- 22 Production and HFC

- 23 Destruction

P

– Hydrogen Production

Q

– Iron & Steel Production

S

– Lime Manufacturing

U

– Miscellaneous Uses of Carbonate

V

– Nitric Acid Production

X

– Petrochemical Production

Y

– Petroleum Refineries

Z

– Phosphoric Acid Production

AA

– Pulp & Paper Manufacturing

CC

– Soda Ash Manufacturing

DD

- Electrical Transmission and Distribution Equipment Use

FF

- Underground Coal Mines

HH

– Municipal Solid Waste Landfills

II

– Industrial Wastewater Treatment

LL

– Suppliers of Coal

- based Liquid Fuels

### 3 

### Subpart

MM

– Suppliers of Petroleum Products

NN

– Suppliers of Natural Gas and Natural Gas Liquids

OO

– Suppliers of Industrial Greenhouse Gases

PP

– Suppliers of Carbon Dioxide

RR

- Geologic Sequestration of Carbon Dioxide

TT

- Industrial Waste Landfills

UU

- Injection of Carbon Dioxide



## 3.0 SUMMARY OF TECHNICAL CORRECTION S AND OTHER AMENDMEN TS
The following table summarizes the amendments proposed for various subparts of Part 98

which are being addressed by the proposed 2015 Revisions and Confidentiality Determinations for Data Elements Under the Greenhouse Gas Reporting Rule

.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

A 98.2(a)(1) (1) A facility that contains any source category that is listed
in Table A

- 3 of this subpart in any calendar year starting in

2010 . 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. (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 Tab le A

- 4 of this subpart. Corrects requirement for consistency with Table

A

- 3.

A 98.2(i)(1) (1) ... The owner or operator must maintain the corresponding records required under §98.3(g) for each of the five consecutive years 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. (1) ... The owner or operator must maintain t he corresponding records required under § 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. See preamble text for explanation.

A 98.2(i)(2) (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 unde r §98.3(g) for each of the three consecutive years 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 me tric 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 notif ication
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 emiss ions less than 15,000 tons CO2e per year. The owner or operator must maintain the corresponding records required under § 98.3(g) for each of the three consecutive years and retain such records for three years prior to notification of discontinuation of

rep orting 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. See preamble text for explanation.

A 98.2(i)(3) (3) If the operations of a facility or supplier are changed such that all applicable GHG

- emitting processes and operations listed in paragraphs (a)(1) through (a)(4) of this (3) If the operations of a facility or suppli er are changed such that all applicable processes and operations subject to paragraphs (a)(1) through (4) of this section cease to See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change section cease to operate, then the owner or operator is exempt from reporting in t he 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 GHG

- emitting processes

a nd operations 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. The owner or operator must resume reporting for any future calendar year during which any of the GHG

- emitting processes or operations resume operation. operate, then the owner or operator may discontinue complying with this part for the reporting years following the year in w hich 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 own er 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 Admini strator 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)
doe s 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 r eporting for any future calendar year during which any of the GHG

- emitting processes or operations resume operation.

A 98.2(i) (4) and (5) None (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 in dividually to each petroleum refinery, fractionator of natural gas liquids, local natural gas distribution company, and producer of CO 2 , N 2 O, or fluorinated greenhouse gases (e.g., a supplier of industrial greenhouse gases might qualify to discontinue repo rting as an exporter of industrial greenhouse gases but still be See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change required to report as an importer; or a company might qualify to discontinue reporting as a supplier of industrial greenhouse gases under subpart OO but still be required to report as a suppl ier of carbon dioxide under subpart PP). (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 ope ration 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 So urce Category" as specified in an applicable subpart.

A 98.2(i)(6) None (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. See preamble text for explanation.

A 98.3(c)(4)(iii) (iii) Annual emissions from each applicable source category, expressed in metric tons of each applicable GHG listed in paragraphs (c)(4)(iii)(A) through (c)(4)(iii)(E) of this section. (iii) Annual emissions from each applicable source category, expressed in metric tons of each applicable GHG listed in paragraphs (c)(4)(iii)(A) through (c)(4)(iii)(F) of this section. Corre cts reference.

A 98.3(c)(4)(iii)( G) None (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 m ethod 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 See preamble text for explanation.

### 7 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change 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 c hemical formula.

A 98.3(c)(5)(ii) (ii) Quantity of each GHG from each applicable supply category in Table A

- 5 to this subpar t

, expressed in metric
tons of CO2e. (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 assig ned by EPA’s Substance Registry Services. ( C ) Linear c hemical formula. See preamble text for explanation.

A 98.3(c)(8) (8) Each data element 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 data element. (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 m issing data procedure was used for each parameter. Parameters include not only reported data elements, but any data element required for monitoring and calculating emissions. See preamble text for explanation.

A 98.3(d)(1)(i) (i) Monitoring methods currently used by the facility that do not meet the specifications of an relevant subpart. (i) Monitoring methods currently used by the facility that do not meet the specifications of a relevant subpart. Editorial correction.

A 98.3(h)(4) (4) Not withstanding 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
grante d for 30 days. The Administrator may grant an additional extension beyond the automatic 30

- day (4) Not withstanding 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 3 0 days. The Administrator may grant an additional extension beyond the automatic 30

- day extension See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change extension if the owner or operator submits a request for an additional extension and the request is received by the Administrator at least 5 business days 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) 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. 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 automat ic 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) 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.

A 98.4(i)(iv)(6) None (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 public ation 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. See preamble text for explanation.

A 98.6 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 to a single location for treatment (thermal destru ction) 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 to the surface of the landfill where an opening or pipe (vent) is installed to allow for natural gas
flow. Gas collection system or landfill gas collection system means a system of pipes used to collect landfill gas from different
loca tions 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 compre ssor. 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 (ve nt) 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 See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change never recovered or thermally destroyed prior to release to the atmosphere.

A 98.6 None 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. Adds definition to clarify meaning of term as used
in the rule.

A 98.6 Ventilation hole or shaft means a vent hole or shaft employed at an underground coal mine to serve as the outlet or conduit to move air from the ventilation system
out of the mine. Ventilation hole or shaft means a vent hole, shaft, mine portal, adit or other mine entrance or exit s employed at an underground coal mine to serve as the outlet or conduit to move air from the ventilation system out of the mine. See preamble text for explanation.

A 98.7(e)(33) (33) ASTM D6866

- 08 Standard Test Methods for Determining the Biobased Content of Solid, Liquid, and Gaseous Samples Using Radiocarbon Analysis, IBR approved for § 98.34(d), § 98.34(e), and § 98.36(e). (33) ASTM D6866

- 12 Standard Test Methods for Determining the Biobased Content of Solid, Liquid, and Gaseous Samples Using Rad iocarbon Analysis, IBR approved for § 98.34(d), § 98.34(e), and § 98.36(e). See preamble text for explanation.

A 98.7(l)(1) (l)(1) General Coal Mine Inspection Procedures and Inspection Tracking System, Handbook Number: PH

- 08

- V

- 1, January 1, 2008, IBR app roved for § 98.324(b). (l)(1) Coal Mine Safety and Health General Inspection Procedures Handbook, Handbook Number: PH13

- V

- 1, February 2013, IBR approved for § 98.324(b). Harmonizing change with proposed 40 CFR 98.324(b)(1).

A Table A

- 3;
Table A

- 4;
Table A

- 5 Table A

- 3, Table A

- 4, and Table A

- 5 See Appendix A for changes to Table A

- 3, A

- 4, and A

- 5. Revises table text from "Applicable in 2010 and
Future Years" to "Applicable in Reporting
Year 2010 and Future
Years".

A Table A

- 5 Table A

- 5 See Appendix A for changes to Table A

- 5. Harmonizing changes with proposed 40 CFR

98.410.

C 98.33(a)(2)(ii) (A) (HHV)annual = Weighted annual average high heat value of the fuel (mmBtu per mass or volume). (HHV)I = Measured high heat value of the fuel, for month “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 month “i,” from company records (express mass in short

tons for solid fuel, volume in standard cubic feet for gaseous fuel, and volume in gallons for liquid fuel). (HHV)annual = Weighted annual average high heat value of the fuel (mmBtu per mas s or volume). (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 volum e 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 See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change n = Number of months in the year that the fuel is burned in
the unit. for solid fuel, volume in standard cubic feet (e.g., for gaseous fuel, and volume in gallons for liq uid fuel). n = Number of sample periods in the year.

C 98.33(a)(5)(i)( C), (ii)(C), and (iii)(C) (i)(C) Divide the cumulative annual CO 2 mass emissions value by 1.1 to convert it to metric tons; (ii)(C) Divide the cumulative annual CO 2 mass emissions value by 1.1 to convert it to metric tons; (iii)(C) Divide the cumulative annual CO 2 mass emissions value by 1.1 to convert it to metric tons. (i)(C) Divide the cumulative annual CO 2 mass emissions value by 1.1023 to c onvert it to metric tons.; (ii)(C) Divide the cumulative annual CO 2 mass emissions value by 1.1023 to convert it to metric tons.; (iii)(C) Divide the cumulative annual CO 2 mass emissions value by 1.1023 to convert it to metric tons. Corrects conversion
f actors for consistency throughout rule.

C 98.34(d) (d) Except as otherwise provided in §98.33 (b)(1)(vi) and (b)(1)(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

- 08 Standard Test Methods for Determining the Biobased Content of Solid, Liquid, and Gaseous Samples Using Radiocarbon Analysis (incorporated by reference, see §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 §98.7). Perform the ASTM D7459

- 08 sampling and the

ASTM D6866

- 08 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 facil ity 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 a t 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 fractio n from the 24

- hour test. There must be no overlapping of the 8

- hour and 24

- (d) Except as otherwise provided in §98.33 (b)(1)(vi) and (b)(1)(vii), wh en 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 th e Biobased Content of Solid, Liquid, and Gaseous Samples Using Radiocarbon Analysis (incorporated by reference, see §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 §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 g as 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 a nd 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 See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change 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 ye ar, 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. Sepa rate 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 t he 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. the dem onstration 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 a n 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 emi ssions 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 fue l source, testing at only one of the units is
sufficient.

C 98.34(e) (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

- 08 (incorporated by reference, see §98.7) and ASTM D7459

- 08 (incorporated by reference, see §98.7) may be used to determine the biogenic portion of the CO2 emissions in every calendar quarter in w hich 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. (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 (incorporate d by reference, see §98.7) and ASTM D7459

- 08 (incorporated by reference, see §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 pr ocedures 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. See preamble text for explanation.

C 98.3 6(c)(1)(iii) [Reserved] (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, exclu ding units less than 10 (mmBtu/hr). See preamble text for explanation.

C 98.36(c)(3)(ii) [Reserved] (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 See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change capacities for all units served by the comm on pipe, excluding units less than 10 (mmBtu/hr).

C 98.36(e)(2)(i) (i) For the Tier 1 Calculation Methodology, report the total quantity of each type of fuel combusted in the unit or group of aggregated units (as applica ble) 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. (i) For the Tier 1 Calculation Methodology, report: (A) The total quantit y 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 n atural 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. See preamble text for explanation.

C 98.36(e)(2)(x) (x) When ASTM methods D7459

- 08 (incorporated by reference, see § 98.7) and D6866

- 08 (incorporated by reference, see § 98.7) are used to determine the biogenic portion of the annual CO2 emissions from MSW combustion, as described in § 98.34(d), report: (A) The results of each quarterly sample analysi s, expressed as a decimal fraction (e.g., if the biogenic fraction of the CO2 emissions from MSW combustion is 30 percent, report 0.30). (B) The annual biogenic CO2 mass emissions from MSW combustion, in metric tons. (x) When ASTM methods D7459

- 08 (incorpo rated by reference, see § 98.7) and D6866

- 12 (incorporated by reference, see § 98.7) are used to determine the biogenic portion of the annual CO2 emissions from MSW combustion, as described in § 98.34(d), report: (A) The results of each quarterly sample an alysis, expressed as a decimal fraction (e.g., if the biogenic fraction of the CO2 emissions from MSW combustion is 30 percent, report 0.30). (B) The annual biogenic CO2 mass emissions from MSW combustion, in metric tons. See preamble text for explanation.

C 98.36(e)(2)(xi) (xi) When ASTM methods D7459

- 08 (incorporated by reference, see § 98.7) and D6866

- 08 (incorporated by reference, see § 98.7) are used in accordance with § 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 d ecimal fraction (e.g., if the biogenic fraction of the CO2 emissions is 30 percent, report 0.30). (xi) When ASTM methods D7459

- 08 (incorporated by reference, see § 98.7) and D6866

- 12 (incorporated by reference, see § 98.7) are used in accordance with § 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 s hall 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). See preamble text for explanation.

C 98.37(a) (a) The applicable records specified in §§ 98.34(f) and (g), 98.35(b), and 98.36(e). (a) The applicable records specified in §§ 98.34(f), 98.35(b), and 98.36(e). Corrects reference.

C 98.37(b)(37) None (37) Moisture content used to calculate the wood and wood
residuals wet basis HHV (percent), if applicable (Equations C

1 and C

- 8). See preamble text for explanation.

### 13 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

C Tables C

- 1 &

C

- 2 Tables C

- 1 and C

- 2 See Appendix A for changes to Tables C

- 1 and C

- 2. See preamble text for explanation.

E 98.53(a)(2) (2) Request Administrator approval for an alternative method of determining N 2 O emissions according to paragraphs (a)(2)(i) and (ii) of this section. (i) You must submit the request within 45 days following promulgation of this subpart or within the first 30 days of each subsequent reporting year. (ii) If the Administrator does not approve your requested alternative method within 150 days of the end of the reporting year, you must determine the N 2 O emissions for the current reporting period using the procedures specified

in paragraphs (b) through (h) of this section. (2) Request Administrator approval for an alternative method of determining N 2 O emissions according to paragraphs (a)(2)(i) through (iv) of this section. (i) If you received Administrator approval for an alternat ive method of determining N 2 O 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 alter native 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 N 2 O emissions for the current reporting period using the procedures specified in paragraph (a)(1) of this section. See preamble text for explanation.

E 98.56(f) (f) Types of abatement technologies used (if applicable). (f) Types of abatement technologies used and date of installation for each (if applicable). See preamble text for explanation.

F 98.65(a) (a) Where anode or paste consumption data are missing,

CO 2 emissions can be estimated from aluminum production per Equation F

- 8 of this section.

ECO 2 = EF p x MP p + EF s x MP s (Eq. F

- 8) (a) Where anode or paste consumption data are missing,

CO 2 emissions can be estimated from aluminum production by using Equa tion F

- 9 of this section.

ECO 2 = EF p x MP p + EF s x MP s (Eq. F

- 9) Corrects equation
reference.

F 98.66(c)(2) and (c)(3) (c)(2) [Reserved]; (c)(3) [Reserved] (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

CF 4 /metric ton Al)/(mV/cell day)), potline overvoltage (mV/cell day), current efficiency (%).); (c)(3) Smelter

- specific slope coefficients (or overvoltage
emission fa ctors) and the last date when the smelter

- specific slope coefficients (or overvoltage emission factors) were
measured. See preamble text for explanation.

### 14 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

G 98.74(f) (f) [Reserved] (f) You may use company records or an engineering estimate
to determine the annual ammonia production and the annual methanol production. See preamble text for explanation.

G 98.76(a) If a CEMS is used to measure CO2 emissions, then you must report the relevant information required under § 98.36 for
the Tier 4 Calculation Methodology and the information in paragraphs (a)(1) and (2) of this section: If a CEMS is used to measure CO2 emissions, then you must report the relevant information required under § 98.36 for the Tier 4 Calculation Methodology and the information in

par agraphs (a)(1) through (3) of this section: See preamble text for explanation.

G 98.76(a)(3) None (3) Annual ammonia production (metric tons, sum of all process units reported within subpart G). See preamble text for explanation.

G 98.76(b)(2) and (b)(7) (b)(2) [Reserved]; (b)(7) [Reserved] (b)(2) Annual quantity of each type of feedstock consumed for ammonia manufacturing (scf of feedstock or gallons of feedstock or kg of feedstock); (b)(7) Annual average carbon content of each type of
feedstock consum ed. See preamble text for explanation.

G 98.76(b)(15) (15) Annual methanol production for each process unit (metric tons). (15) Annual methanol production for each process unit (metric tons), regardless of whether the methanol is subsequently destroyed, vented, or sold as product. See preamble text for explanation.

I 98.93(a)(1) (1) If you manufacture semiconductors, you must adhere to the procedures in paragraphs (a)(2)(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, 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 this paragraph (a). (1) If you manufacture semiconductors, you must adhere to the procedures in paragraphs (a)(1)(i) through (iii) of this
section. You must calcu late annual emissions of each input gas and of each by

- product gas using Equations I

- 6 and I

- 7, 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 this paragraph (a). Corrects reference.

I 98.93, Eq. I

- 12 N il = Number of containers of size and type l returned to the gas distributor containing the standard heel of input gas i. N il = 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. Clarifies that equation
term is collected on a
fab

- basis.

I 98.93, Eq. I

- 12 F il = Full capacity of containers of size and type l containing input gas i, on a fab basis (kg). F il = Full capacity of containers of size and type l containing input gas i (kg). Corrects equation term.

I 98.93(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 destroyed in abatement systems for each stack system as calculated by Equation I

- 24 of this subpart. ... 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 byproduct gas k destroyed in abatement systems for each stack system as calculated by Equations I

24A and I

- 24B of this subpart. ... Harmonizing change with prop osed edits to Equation I

- 24.

### 15 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

I 98.93(i)(1)(iv) (iv) ...You may account for such a change using a quantifiable metric (e.g., the ratio of the number 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. (iv) ...You may account for such a change using a quantifiabl e 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 th e previous reporting year), engineering judgment, or other industry standard practice. Editorial correction.

I 98.93, Eq. I

- 17 Corrects equation terms (updates "Qj" and "s=1" to "Qs" and "m=1").

I 98.93, Eq. I

- 19 d if = 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

- 24 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. d if = 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 (expres sed 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. Harmonizing change with proposed edits to Equation I

- 24.

I 98.93, Eq. I

- 20 d kf = 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

- 24 of this subpart (expressed as decimal fraction). d kf = 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). Harmonizing change with proposed edits to Equation I

- 24.

I 98.93, Eq. I

- 21 d if = 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

- 24 of this subpart (expressed as decimal fraction). d if = Fr action 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). Harmonizing change with proposed edits to Equation I

- 24.

I 98.93, Eq. I

- 22 dk f = 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

- 24 of this subpart (expressed as decimal fraction). dk f = 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 Equa tion I

- 24B of this subpart (expressed as decimal fraction). Harmonizing change with proposed edits to Equation I

- 24.

I 98.33(i)(3)(viii ) (viii) When using the stack testing option described in this paragraph (i), you must calculate the weighted

- average fraction of fluorinated input gas i be destroyed or removed in abatement systems for each fab f, as applicable, by using Equation I

- 24 of th is subpart. (viii) When using the stack testing option described in this paragraph (i), you must calculate the weighted

- average fraction of each fluorinated input gas i and each fluorinated byproduct gas k destroyed or removed in abatement systems for each fab f, as applicable, by using Equation I

- 24A Harmonizing change with proposed edits to Equation I

- 24.

### 16 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change (for input gases) and Equation I

- 24B (for byproduct gases) of this subpart.

I 98.93, Eq. I

- 24 None See preamble text for explanation.

I 98.93, Eq. I

24A None (Eq. I

- 24

- A) See preamble text for explanation.

I 98.93, Eq. I

24B None (Eq. I

- 24

- B) See preamble text for explanation.

I 98.93, Eq. I

24A and I

- 24B Where:
d if =The average weighted fraction of fluorinated GHG input gas i destroyed or removed in abatement systems in fab f (expressed as a decimal fraction).

C ijf =The amount of fluorinated GHG input gas i consumed for process type j fed into abatement systems in fa b f as calculated using Equation I

- 13 of this subpart (kg).

DRE ij =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 a ccording to § 98.94(f).
f=fab. i=Fluorinated GHG input gas. j=Process type. Where:
d if = The average weighted fraction of fluorinated GHG input gas i destroyed or removed in abatement systems in fab f (expressed as a decimal fraction).
d kf = The average weighted fraction of fluorinated GHG byproduct gas k destroyed or removed in abatement systems in fab f (expressed as a decimal fraction).

C ijf = The amount of fluorinated GHG input gas i consumed for process type j fed into abatement system s in fab f as calculated using Equation I

- 13 of this subpart (kg). (1

- U ij ) = The default emission factor for input gas i used in process type j, from applicable Table I

- 3 to I

- 7 of this subpart.

B ijk = The default by

- product gas formation rate factor for byproduct gas k from input gas i used in process type j, from applicable Table I

- 3 to I

- 7 of this subpart.

DRE ij = 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 § 98.94(f).

DRE jk = Destruction or removal efficiency for fluorinated GHG byproduct 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 § 98.94(f).
f = fab. i = Fluorinated GHG input gas. See preamble text for explanation.

### 17 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change
j = Process type.

I 98.93(i)(4) (4) ... You must use, in place of the term a ij , the fraction of fluorinated GHG meeting th e 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 th e results of Equations I

- 24 of this subpart in place of the terms d ij in Equation I

- 8 of this subpart and d jk in Equation I

- 9 of this subpart 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 UT ij

. (4) ... You must use, in place of the term a ij , 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 d ij 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 UT ij

. Harmonizing change with proposed edits to Equation I

- 24.

I 98.94(f) (f) If your fab employs abatement systems a nd 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 98.93(i), you
must comp ly with the requirements of paragraphs (f)(1) through (f)(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 calcula tions under §98.93(a), (b), and/or (i), you must also adhere to procedures in paragraph (f)(4) of this section. (f) If your fab employs abatement systems and you elect to reflect emission reductions due to these systems, or if your fab employs abatement sy stems designed for fluorinated GHG abatement and you elect to calculate fluorinated GHG emissions using the stack test method under § 98.93(i), you must comply with the requirements of paragraphs (f)(1) through (f)(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 § 98.93(a), (b), and/or (i), you must also adhere to procedures in paragraph (f)(4) of this section. Editorial correction.

I 98.94(j)(5)(ii) (ii) .... 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 way that triggers the re

- test criteria in paragraph (j)(8) of this section. ... (ii) .... If the criteria specified in pa ragraphs (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 f ab operations are changed in a way that triggers the re

- test criteria in paragraph (j)(8) of this section. ... Editorial correction.

I 98.96(c)(2) (2) 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. (2) When you use the procedures specified in § 98.93(a) of this subpart, 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. Clarifies requirement.

### 18 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

I 98.96(d) (d) The method of emissions calculation used in § 98.93. (d) The method of emissions cal c u l ation used in § 98.93 for
each fab. Clarifies that data
element is collected on a
fab

- basis.

I 98.96(e) (e) Annual production in terms of substrate surface area (e.g., silicon, PV

- cell, glass) (e) Annual production in terms of substrate surface area (e.g., silicon, PV

- cell, glass) for each fab, including specification of the substrate. Clarifies data elemen t.

I 98.96(r)(2) (2) ... d if = Fraction of fluorinated GHG i destroyed or removed in abatement systems connected to process tools in fab f, which you used to calculate total emissions according to the procedures in § 98.93(i)(3) (expressed as a
decimal fraction). (2) ... d if = Fraction of fluorinated GHG i destroyed or removed in abatement systems connected to process tools in fab f, as calculated from Equation I

- 24A, which you used to calculate total emissions according to the procedures in § 98.93(i)(3) (expressed as a decimal fraction). Harmonizing change with proposed edits to Equation I

- 24.

I 98.96(r)(2) (2) ... d kf = Fraction of fluorinated GHG by

- product k destroyed or removed in abatement systems connected to process tools in fab f, which you used to calculate total emissions according to the procedures in § 98.93(i)(3) (expressed as a decimal fraction). (2) ... d kf = Fraction of fluorinated GHG by

- product k destroyed or removed in abatement systems connected to process tools in fab f, as calculated fro m Equation I

- 24B, which you used to calculate total emissions according to the procedures in § 98.93(i)(3) (expressed as a decimal fraction). Harmonizing change with proposed edits to Equation I

- 24.

I 98.96(y)(2)(iv) (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. (iv) It must provide any utilization a nd 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
formatio n 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. See preamble text for explanation.

I 98.97(d)(5) (5) In addition to the inventory specified in §98.96(p), the information in paragraphs (d)(5)(i) though (iii) of this

section: (5) In addition to the inventory specified in § 98.96(p), the information in paragraphs (d)(5)(i) through (iii) of this

section: Editorial correction.

I 98.97(d)(7) (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 Equation I

- 24 of this subpart, if applicable. The inputs should incl ude an indication of (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 Harmonizing change with proposed edits to Equation I

- 24.

### 19 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change whether each value for destruction or removal efficiency is
a default value or a measured site

- specific value. whether each value for destruction or removal efficiency is a
default value or a measured s ite

- specific value.

I Table I

- 3 Table I

- 3 See Appendix A for changes to Table I

- 3. Corrects typographical
and calculation errors in
emission factors for etching/wafer cleaning and remote plasma chamber cleaning

. N 98.144(b) (b) 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; ... (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; ... See preamble text for explanation.

N 98.144(c) (c) 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. (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 sam pling and chemical analysis. See preamble text for explanation.

N 98.144(d) (d) 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. 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.). (d) Unless you use the default value of 1.0, you must
determine o n 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 t esting method published by an industry consensus standards organization (e.g., ASTM, ASME, API, etc.). See preamble text for explanation.

N 98.146(b)(5) (5) Results of all tests 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 (b)(5)(iii) of this

section. (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 (b)(5)(iii)
of this section. See preamble text for explanation.

N 98.146(b)(7) (7) Method used to determine decimal fraction of
calcination. (7) Method used to determine decimal fraction of calcination, unless you used the default value of 1.0. See preamble text for explanation.

N 98.147(b)(3) (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. (3) Data on carbonate

- based mineral mass fractions provided by the raw material supplier for all raw materials consumed annually and inc luded in calculating process emissions in Equation N

- 1 of this subpart, if applicable. See preamble text for explanation.

### 2 0 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

N 98.147(b)(4) (4) Results of all tests 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 (b)(4)(v) of this section. (4) Results of all tests, if applicable, used to verify the
carbonate

- based mineral mass fraction for each carbo nate

based raw material charged to a continuous glass melting furnace, including the data specified in paragraphs (b)(4)(i) through (b)(4)(v) of this section. See preamble text for explanation.

N 98.147(d)(2) (2) Annual amount of each carbonate

- based raw material charged to each continuous glass melting furnace (tons) (Equation N

- 1). (2) Annual amount of each carbonate

- based raw material charged to each continuous glass melting furnace (tons) (Equation N

- 1). Editorial correction.

N 98.147(d)(3) (3) Decimal fraction of each calcination achieved for
carbonate

- based raw material for each continuous glass melting furnace (specify the default value, if used, or the value determined according to §98.144) (percentage, expressed as a decimal) (Equation N

- 1). (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 § 98.144) (percentage, expressed as a decimal) (Equation N

- 1). Editorial correction.

O 98.156(a) (a) In addition to the information required by §98.3(c), the

HCFC

- 22 production facility shall report the following information at the facility level: (a) In addition to the information required by § 98.3(c), the

HCFC

- 22 production facility shall report the following
information for each HCFC

- 22 production process: See preamble text for explanation.

O 98.156(d) (d) If the HFC

- 23 concentration measured pursuant to §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 following: (1) [Reserved] (2) Concentration (mass fraction) of HFC

- 23 at the outlet of
the destruction device. (3) Flow rate at the outlet of the destruc tion device in kg/hr. (4) Emission rate (in kg/hr) calculated from paragraphs (d)(2) and (d)(3) of this section. (5) [Reserved] (d) If the HFC

- 23 concentration measured pursuant to § 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 § 98.154(l)(1) or (l)(2) has been used for the
calculation. See preamble text for explanation.

P 98.163(b)(3) Equation P

- 3 CO 2 = Annual CO 2 emissions from fuel and feedstock consumption in metric tons per month (metric tons/yr). CO 2 = Annual CO 2 emissions from fuel and feedstock consumption (metric tons/yr). Editorial correction.

P 98.164(b)(1) (1) Calibrate all oil and gas flow meters that are used to measure liquid and gaseous feedstock volumes (except for gas billing meters) according to the monitoring and QA/QC requirements for the Tier 3 methodology in §98.34(b)(1). Perform oil tank drop measur ements (if used to quantify liquid fuel or feedstock consumption) according to §98.34(b)(2). Calibrate all solids weighing equipment according to the procedures in §98.3(i). (1) Calibrate all oil and gas flow meters that are used to measure liquid and gase ous fuel and feedstock volumes (except for gas billing meters) according to the monitoring and QA/QC requirements for the Tier 3 methodology in § 98.34(b)(1). Perform oil tank drop measurements (if used to quantify liquid fuel or feedstock consumption) acc ording to § 98.34(b)(2). Calibrate all solids weighing equipment according to the procedures in § 98.3(i). Clarifies that calibration requirements apply to
fuel meters as well as
feedstock meters.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

P 98.166(b)(4) (4) Annual quantity of ammonia produced, if applicable (metric tons). (4) Annual quantity of ammonia intentionally produced as a desired product, if applicable (metric tons). Clarifies data element.

P 98.166(d) (d) Annual quantity of carbon other than CO2 collected and
transferred off site in either gas, liquid, or solid forms (kg carbon). (d) Annual quantity of carbon other than CO 2 collected and transferred off site in either gas, liquid, or solid forms (kg carbon), excluding methanol. Clarifies data element.

P 98.166(e) (e) Annual methanol production (metric tons) for each process unit. (e) Annual quantity of methanol intentionally produced as a desired product, if applicable, (metric tons) for each process

unit. Clarifies data element.

Q Equation Q

- 5 Corrects equation term (updates last term to
“C R ”).

Q Equation Q

10 Corrects equation term (updates “lux” to “Flux”).

Q Equation Q

11 Corrects equation (removes “+ I”).

Q Equation Q

12 Corrects equation term (updates “Cg,f,I” to “Cgf,i”).

Q Equation Q

12 n = Number of gaseous, liquid, and solid fuel input to each process unit as used in Equation Q

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

- 9. Editorial correction.

S 98.196(b) (b) If a CEMS is not used to measure CO 2 emissions, then you must report the information listed in paragraphs (b)(1) through (18) of this section. (b) If a CEMS is not used to measure CO 2 emissions, then you must report the information listed in paragraphs (b)(1) through (21) of this section. See preamble text for explanation.

S 98.196(b)(19)

- (21) None (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. See preamble text for explanation.

U 98.216(e) (e) If you followed the calculation method of §98.213(b)(1)(i), you must report the information in paragraphs (e)(1) through (e)(3) of this section. (e) If you followed the calculation method of § 98.213(a), you must report the information in paragraphs (e)(1) through (e)(3) of this section. Corrects reference.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

V 98.220 A nitric acid production facility uses one or more trains to produce weak nitric acid (30 to 70 percent in strength). A nitric acid train produces weak nitric acid through the catalytic oxidation of ammonia. 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. See preamble text for explanation.

V 98.223(a)(2) (2) Request Administrator approval for an alternative method of determining N 2 O emissions according to paragraphs (a)(2)(i) and (a)(2)(ii) of this section. (i) You must submit the request within 45 days following promulgation of this subpart or within the first 30 days of each subsequent reporting year. (ii) If the Administrator does not approve your requested alternative method within 150 days of the end of the reporting year, you must determine the N 2 O emissions for the current reporting period using the procedures specified in paragraph (a)(1) of this section. (2) Request Administra tor approval for an alternative method of determining N 2 O emissions according to paragraphs (a)(2)(i) through (a)(2)(iv) of this section. (i) If you received Administrator approval for an alternative method of determining N 2 O emissions in the previous

repo rting 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 mu st 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
report ing year, you must determine the N 2 O emissions for the current reporting period using the procedures specified in paragraph (a)(1) of this section. See preamble text for explanation.

V 98.226(h) (h) Abatement technologies used (if applicable). (h) Abatement technologies used (if applicable) and date of installation of abatement technology. See preamble text for explanation.

X 98.240(a) (a) 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. The source category includes processes that produce the petrochemical as an intermediate in the on

site production of othe r chemicals as well as processes that produce the petrochemical as an end product for sale or shipment off site. (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 petrochemic al 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. See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change (3) When et hylene 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 § 98.243(c). If you elect to co nsider the integrated process to be the petrochemical process, then the mass balance must be performed over the entire integrated

process.
X 98.243(c)(3) (3) Collect a sample of each feedstock and product at least

once p er month and determine the carbon content of each sample according to the procedures of §98.244(b)(4). If multiple valid carbon content measurements are made during the monthly measurement period, average them arithmetically. However, if a particular liqui d 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 c onducted 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 §98.244(b)(4). (3) Collect a sample of each feedstock and product at least

once per mon th 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 § 98.244(b)(4). If multiple valid molecular weight or
carbon content measurements are made d uring 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 spec ified in § 98.244(b)(4). See preamble text for explanation.

X 98.243(c)(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 carbon content in accordance with paragraphs (c)(4)(i) through (iii) of this section. (i) Calculate the carbon content assuming 100 percent of
that feedstock or product is the specific compound. ... (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. ... See preamble text for explanation.

X 98.246(a)(5) (5) Annual quantity of each type of petrochemical produced from each process unit (metric tons). (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 See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change ethylene dichloride productio n (metric tons) or both the measured quantity of vinyl chloride monomer production (metric tons) and an estimate of the ethylene dichloride production (metric tons).

X 98.246(a)(6) (6) For each feedstock and product, pro vide the information specified in paragraphs (a)(6)(i) through (a)(6)(iii) of this section. (i) Name of each method used to determine carbon content or molecular weight in accordance with §98.244(b)(4); (ii) Description of each type of device (e.g., flow m eter, weighing device) used to determine flow or mass in accordance with §98.244(b)(1) through (3). (iii) Identification of each method (i.e., method number, title, or other description) used to determine flow or mass in accordance with §98.244(b)(1) throu gh (3). (6) For each feedstock and product, provide the information specified in paragraphs (a)(6)(i) through (a)(6)(iii) of this

section. (i) Name of each method used to determine carbon content or molecular weight in accordance with § 98.244(b)(4); (ii) Description of each type of measurement device (e.g., flow meter, weighing device) used to determine volume or mass in accordance with § 98.244(b)(1) through (3). (iii) Identification of each method (i.e., method number, title, or other description) used t o determine volume or mass in accordance with § 98.244(b)(1) through (3). Clarifies requirement.

X 98.246(a)(14) and (15) None (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 pr oduct. (15) For each gaseous feedstock and product, the annual average of the measurements of molecular weight in units of kg per kg mole. See preamble text for explanation.

X 98.246(b)(2) and (3) (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 §98.36(c)(2) and (e)(2)(vi) for the Tier 4 calculation methodology. Sections 98.36(c)(2)(ii) and (c)(2)(ix) do not ap ply 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 §98.36(b)(6), (b)(7), and (e)(2)(vi). (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 § 98.36(c)(2) and (e)(2)(vi) for the Tier 4 calculation methodology. Sections 98.36(c)(2)(ii), (c)(2)(ix) and ( c)(2)(x) do 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 § 98.36(b)(6), (b)(7), (b)(9)(i), (b)(9)(ii) and (e)(2)(vi). Clarifie s reporting requirements.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

X 98.246(b)(8) (8) Annual quantity of each type of petrochemical produced from each process unit (metric tons). (8) Annual quantity of each type of petrochemical produced from each process unit (metric tons). If your petrochemica l 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 t he ethylene dichloride product (metric tons). See preamble text for explanation.

X 98.247(a) (a) If you comply with the CEMS measurement methodology in §98.243(b), then you must retain under this subpart the records required for the Tier 4 Calculation Methodology in §98.37, records of the procedures used to develop estimates of the fraction of total emissions attributable to combustion of petrochemical process off

gas as required in §98.246(b), and records of any annual average HHV calculations. (a) If you comply with the CEMS measurement methodology in § 98.243(b), then you must retain under this subpart the records required for the Tier 4 Calculation Methodology in § 98.37, records of the procedures used to develop estimates
of the fraction of total em issions attributable to petrochemical processing and combustion of petrochemical process off

- gas as required in § 98.246(b), and records of any annual average HHV calculations. Clarifies requirement.

X 98.248 Product , as used in §98.243, 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. 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. Cla rifies that definition applies throughout subpart.

Y 98.253(b) (b) For flares, calculate GHG emissions according to the requirements in paragraphs (b)(1) through (b)(3) of this

section. (b) For flares, calculate GHG emissions according to the requirement s in paragraphs (b)(1) through (b)(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. See preamble text for explanation.

Y 98.253(b)(1)(ii i)(B) (B) For periods of normal operation, use the average heating value measured for the fuel gas for the heating value of the flare gas. If heating value is not measured, the heating value may be estimated from historic data or engineering calculations (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. Clarifies requirement.

Y 98.253(h)(1) (1) For uncontrolled asphalt blowing operations or asphalt blowing operations controlled by vapor scrubbing, calculate (1) For uncontrolled asphalt blowing operations or as phalt blowing operations controlled either by vapor scrubbing or See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

CO 2 and CH 4 emissions using Equations Y

- 14 and Y

- 15 of this section, respectively. by another non

- combustion control device, calculate CO 2 and CH 4 emissions using Equations Y

- 14 and Y

- 15 of this section, respectively.

Y 98.253(h)(2) (2) For asphalt blowing operations controlled by thermal oxidizer or flare, calculate CO 2 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 in cluded 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). (2) For asphalt blowing operations controlled by ei ther a thermal oxidizer, a flare, or other vapor combustion control device, calculate CO 2 using either Equation Y

- 16a or Equation Y

- 16b of this section and calculate CH 4 emissions using Equation Y

- 17 of this section, provided these emissions
are not alread y 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). See preamble text for explanation.

Y 98.253(h) (2); Equation Y

16a 0.98 = Assumed combustion efficiency of thermal oxidizer
or flare. 0.98 = Assumed combustion efficiency of the control device. Harmonizing change with proposed 40 CFR 98.253(h)(2).

Y 98.253(h)(2); Equation Y

16b 0.98 = Assumed combustion efficiency of thermal oxidizer
or flare. 0.98 = Assumed combustion efficiency of the control device. Harmonizing change with proposed 40 CFR 98.253(h)(2).

Y 98.253(h)(2), Equation Y

- 17 0.02 = Fraction of methane uncombusted in thermal
oxidizer or flare based on assumed 98% combustion efficiency. 0.02 = Fraction of methane uncombusted in the controlled stream based on assumed 98% combustion efficiency. Harmonizing change with proposed 40 CFR 98.253(h)(2).

Y 98.253(i)(1) and (2) (i) For delayed c oking units, calculate the CH4 emissions from the depressurization of the coking unit vessel (i.e., the “coke drum”) to atmosphere using either of the methods provided in paragraphs (i)(1) or (i)(2), provided no water or
steam is added to the vessel once i t is vented to the atmosphere. You must use the method in paragraph (i)(1) of this section if you add water or steam to the vessel after it is vented to the atmosphere. (1) Use the process vent method in paragraph (j) of this
section to calculate the CH 4 emissions from the depressurization of the coke drum or vessel regardless of
the CH 4 concentration and also calculate the CH 4 emissions from the subsequent opening of the vessel for coke cutting operations using Equation Y

- 18 of this section. If you have coke drums or vessels of different dimensions, use the process vent method in paragraph (j) of this section and (i) For each delayed coking unit, calculate the CH 4 emissions
from delayed decoking operations (venting, draining, deheading, and coke

- cutting) according to the requirements in paragraphs (i)(1) through (i)(5). (1) Determine the typical dry mass of coke produced per cycle from company records of the mass of coke produce d 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 o f this section. 

# ( ) 2

coke bulk drum outage 

### π D M ρ H H 4   × =× − ×     

## ( Eq. Y

- 18a )
Where: See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change
Equation Y

- 18 for each set of coke drums or vessels of the
same size and sum the resultant emissions across each set
of coke drums or vessels to calculate the CH 4 emissions for all delayed coking units. [See Equation Y

- 18] CH4 = Annual methane emissions from the delayed coking unit vessel opening (metric ton/year). N = Cumulative number of vessel openings for all delayed coking unit vessels of th e same dimensions during the year. H = Height of coking unit vessel (feet). PCV = Gauge pressure of the coking vessel when opened to the atmosphere prior to coke cutting or, if the alternative method provided in paragraph (i)(2) of this section is used,

ga uge pressure of the coking vessel when depressurization gases are first routed to the atmosphere (pounds per square inch gauge, psig). 14.7 = Assumed atmospheric pressure (pounds per square inch, psi). fvoid = Volumetric void fraction of coking vessel prio r to steaming (cf gas/cf of vessel); default = 0.6. D = Diameter of coking unit vessel (feet). 16 = Molecular weight of CH4 (kg/kg

- mole). MVC = Molar volume conversion factor (849.5 scf/kg

- mole at 68 °F and 14.7 psia or 836.6 scf/kg

- mole at 60 °F and

14.7 psia). MFCH4 = Mole fraction of methane in coking vessel gas (kg

mole CH 4 /kg

- mole gas, wet basis); default value is 0.01. 0.001 = Conversion factor (metric ton/kg).

(2) Calculate the CH4 emissions from the depressurization vent and subsequent opening of t he vessel for coke cutting operations using Equation Y

- 18 of this section and the pressure of the coking vessel when the depressurization gases are first routed to the atmosphere. If you have coke drums or vessels of different dimensions, use Equation Y

- 18
for each set of coke drums or vessels of the same size and
sum the resultant emissions across each set of coke drums Mcoke = Typical dry mass of coke in the delayed coking unit vessel at the end of the coking cycle (metric tons/cycle). ρbulk = Bulk coke bed density (metric tons per cubic feet; mt/ft 3 ). Use the default value of 0.0191 mt/ft 3 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 (fe et) 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. 

# ( ) 2 coke

water water water particle 

### M π D M ρ H 4 ρ   × =× × −    


## ( Eq. Y

- 18 b)
Where:
Mwater= Mass of water in the d elayed coking unit vessel at the end of the cooling cycle just prior to atmospheric venting (metric tons/cycle). ρwater = Density of water at average temperature of the delayed coking unit vessel at the end of the cooling cycle just prior to atmospheric ve nting (metric tons per cubic feet; mt/ft 3 ). 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) fr om 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. ρparticle = Particle density of coke (metr ic tons per cubic feet; mt/ft 3 ). Use the default value of 0.0382 mt/ft 3 D = Diameter of delayed coking unit vessel (feet).

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

or vessels to calculate the CH 4 emissions for all delayed coking units.

Y 98.256(i)(3) through (5) None (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.

Where: Tinitial = Average temperature of the delayed coking unit
vessel when the drum is first vented to the atmosphere (°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 °F, use Toverhead = 216 °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 °F, use Tbottom =
212 °F.

Wher e: Tinitial = Average temperature of the delayed coking unit vessel when the drum is first vented to the atmosphere (°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. See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change



# ( ) 

# ( ) ( ) ConvLoss water p,water coke p,coke initial fin al

steam

vap 

### 1f M C M C T T M H − × × +× × −

= ∆

( Eq. Y

- 18 e )

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 ju st prior to atmospheric venting (metric tons/cycle). Cp,water = Heat capacity of water (British thermal units per metric ton per degree Fahrenheit; Btu/mt

- °F). Use the default value of 2,205 Btu/mt

- °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

- °F). Use the default value of 584 Btu/mt

- °F. Tinitial = Average temperature of the delay ed coking unit vessel when the drum is first vented to the atmosphere (°F) as determined in paragraph (i)(3) of this section. Tfinal = Temperature of the delayed coking unit vessel when steam generation stops (°F). Use the default value of 212 °F. ΔHvap = 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 CH 4 emissions from decoking operations at each delayed coking unit using Equation Y

- 18f of this section.

Where:

CH 4 = Annual methane emissions from the delayed coking unit’ decoking operations (metric ton/year).

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change Msteam = Mass of steam generated and released per decoking cycle (metric tons/cycle) as determined in paragraph (i)(3) of this section.
EmFDCU = Methane emi ssion factor for delayed coking unit (kilograms CH 4 per metric ton of steam; kg CH 4 /mt steam)
from unit

- specific measurement data. If you do not have

unit

- specific measurement data, use the default value of 7.9 kg CH 4 /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).

Y 98.253(j) (j) For each process vent n ot covered in paragraphs (a) through (i) of this section that can reasonably be expected to contain greater than 2 percent by volume CO 2 or greater than 0.5 percent by volume of CH 4 or greater than 0.01 percent by volume (100 parts per million) of N 2 O, cal culate GHG emissions using Equation Y

- 19 of this section. You must also use Equation Y

- 19 of this section to calculate CH 4 emissions for catalytic reforming unit depressurization and purge vents when methane is used as the purge gas, CH 4 emissions if you e lected to use the method in paragraph (i)(1) of this section, and CO 2 and/or CH 4 emissions, as applicable, if you elected this method as an alternative to the methods in paragraphs (f), (h), or (k) of this section. (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 CO 2 or greater than 0.5 percent by volume of CH 4 or greater than 0.01 percent by volume (100 parts per million) of N 2 O, calculate

GHG emi ssions using Equation Y

- 19 of this section. You must also use Equation Y

- 19 of this section to calculate CH 4 emissions for catalytic reforming unit depressurization and purge vents when methane is used as the purge gas, and CO 2 and/or CH 4 emissions, as applicable, if you elected this method as an alternative to the methods in paragraphs (f), (h), or (k) of this section. See preamble text for explanation.

Y 98.254(j) and (k) (j) Determine the quantity of petroleum process streams using company records. These quantities include the quantity of 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) The owner or operator shall document the procedures used to ensure the accuracy of the estimates of fuel usage, gas composition, and heating value including but not limited to calibration of weighing equipment, fuel flow meters, and other measurement devices. The estimated

acc uracy of measurements made with these devices shall (j) Determine the quantity of petroleum process streams using company records. These quantities include the quantity of cok e 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. (l) The owner or operator shall document the procedures used to ensure the accuracy of the estimates of fuel usage, gas composition, and heating value including but not limited See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change also be recorded, and the technical basis for these estimates shall be provided. to calibration of weighing equipment, fuel flow meters, and other measurement devices. The estimated accuracy of
measurements made with these devices shall also be recorded, and the technical basis for these estimat es shall be provided.

Y 98.256(e)(3) (3) A description of the flare service (general facility flare, unit flare, emergency only or back

- up flare). (3) A description of the flare service (general facility flare,
unit flar e, emergency only or back

- up flare) and an indication of whether or not the flare is serviced by a flare
gas recovery system. See preamble text for explanation.

Y 98.256(e)(6) (6) If you use Equation Y

- 1a of §98.253, an indication of whether daily or weekly measurement periods are used, the annual volume of flare gas combusted (in scf/year) and the annual average molecular weight (in kg/kg

- mole), and annual average carbon content of the flare gas (in kg carbon per kg flare gas). (6) If you use Equation Y

- 1a of § 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 aver age molecular weight (in kg/kg

- mole), or, the annual mass of flare gas combusted (in kg/yr). Allows for reporting mass of flare gas quantities.

Y 98.256(h)(5)(ii )(A) (A) The annual volume of recycled tail gas (in scf/year) only. (A) The annual volume of recycled tail gas (in scf/year). Editorial correction.

Y 98.256(k) (k) For delayed coking units, the owner or operator shall
report: (1) The cumulative annual CH 4 emissions (in metric tons of CH4) for all delayed coking units at the facility. (2) A descri ption of the method used to calculate the CH 4 emissions for each unit (e.g., reference section and equation number). (3) The total number of delayed coking units at the facility; the total number of delayed coking drums at the facility; and, for each coke drum or vessel, the typical drum outage (i.e. the unfilled distance from the top of the drum, in feet). (4) For each set of coking drums that are the same dimensions, the number of coking drums in the set, and the mole fraction of methane in coking gas (in kg

- mole CH4/kg

mole gas, wet basis). (5) The basis for the volumetric void fraction of the coke vessel prior to steaming and the basis for the mole fraction of methane in the coking gas. (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 uni t, in bbl/stream day. (3) Annual quantity of coke produced in the unit during the reporting year, in metric tons. (4) The calculated annual CH 4 emissions (in metric tons of CH4) for the delayed coking unit. (5) The total number of delayed coking vessels (o r 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). (7) An indication of the method used to estimate the average temperature of the coke bed, Tinitial (overhead temperature and Equation Y

- 18c or pressure correlation and Equation Y

- 18d). Harmonizing changes with proposed 40 CFR 98.253(i).

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change (6) If you use Equation Y

- 19 of this subpart, the relevant
informati on required under paragraph (l)(5) of this section
for each set of coke drums or vessels of the same size. (8) An indication of whether a unit

- specific methane
emissions factor or the d efault methane emission factor was used for the delayed coking unit.

Y 98.257(b) (b) Verification software records. You must keep a record of the file generated by the verification software specified

i n §98.5(b) for the applicable data specified in paragraphs (b)(1) through (67) of this section. Retention of this file satisfies the recordkeeping requirement for the data in paragraphs (b)(1) through (67) of this section. (b) Verification software records . You must keep a record of the file generated by the verification software specified in § 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 d ata in paragraphs (b)(1) through (73) of this section. Harmonizing changes with proposed 98.253(i).

Y 98.257(b)(41) through (67) (41) Cumulative number of vessel openings for all delayed coking unit vessels of the same dimensions during the year (Equation Y

- 18 of §98.253). (42) Height of coking unit vessel for each set of coke drums or vessels of the same size (feet) (Equation Y

- 18). (43) Gauge pressure of the coking vessel when opened to the atmosphere prior to coke cutting or, if the alternative method p rovided in §98.253(i)(2) is used, gauge pressure of the coking vessel when depressurization gases are first routed to the atmosphere for each set of coke drums or vessels of the same size (pounds per square inch gauge (psig)) (Equation Y

- 18). (44) Volumetr ic void fraction of coking vessel prior to steaming for each set of coke drums or vessels of the same size (cf gas/cf of vessel) (Equation Y

- 18). (45) Diameter of coking unit vessel for each set of coke drums or vessels of the same size (feet) (Equation Y

- 18). (46 ) Molar volume conversion factor for each set of coke drums or vessels of the same size (scf per kg

- mole) (Equation Y

- 18). (41) Typical dry mass of coke in the delayed coking unit vessel at the end of the coking cycle (metric tons/cycle) from

comp any records or calculated using Equation Y

- 18a (Equations Y

- 18a, Y

- 18b and Y

- 18e of § 98.253) for each delayed coking unit. (42) Internal height of delayed coking unit vessel (feet) (Equation Y

- 18a) 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) for each delayed coking unit. (44) Diameter of delayed cokin g unit vessel (feet) (Equation

Y

- 18a and Y

- 18b) 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) 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) for each
dela yed coking unit. (47) Mass of steam generated and released per decoking cycle (metric tons/cycle) (Equations Y

- 18e and Y

- 18f of § 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 (°F) Harmonizing changes with proposed 98.253(i).

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change (Equations Y

- 18c, Y

- 18d, and Y

- 18e of § 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) for each delayed coking unit. (50) Pressure of the delayed coking unit vessel just prior to opening the atmospheric vent (psig) (Equation Y

- 18d) for each delayed coking unit. (51) Methane emission factor for delayed coking unit (kilograms CH 4 per metric ton of steam; kg CH 4 /mt steam) (Equation Y

- 18f) 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 (Eq uation Y

- 18f) for each delayed coking unit. [(b)(47)

- (67) renumbered to (b)(53)

- (73)]

Y 98.257(b)(59) (b)(59) Specify whether the calculated or default loading factor L specified in §98.253(n) is entered, for e ach liquid loaded to each (methods specified in §98.253(n)). (b)( 65 ) Specify whether the calculated or default loading factor L specified in § 98.253(n) is entered, for each liquid loaded to each vessel (methods specified in § 98.253(n)). Editorial correct ion.

Z 98.266(f)(3) (3) Annual phosphoric acid permitted production capacity (tons) for each wet

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

- process phosphoric acid process line. See preamble text for explanation.

AA 98.273(a)(1) (1) Calculate fossil fuel

- based CO 2 emissions from direct
measurement of fossil fuels consumed and default emissions factors according to the Tier 1 methodology for stationary combustion sources in §98.33 (a)(1). A higher tier from §98.33(a) may be used to calculate fossil fuel

- based

CO 2 emissions if the respective monitoring and QA/QC requirements described in §98.34 are met. (1) Calculate fossil fuel

- based CO 2 emissions from direct
measurement of fossil fuels consumed and default emissions factors according to the Tier 1 methodology for stationary combustion sources in § 98.33(a)(1). Tiers 2 or 3 from § 98.33(a)(2) or (3) may be used to calculate fossil fuel

- b ased

CO 2 emissions if the respective monitoring and QA/QC requirements described in § 98.34 are met. See preamble text for explanation.

AA 98.273(b)(1) (1) Calculate fossil CO 2 emissions from fossil fuels from
direct measurement of fossil fuels consumed a nd default emissions factors according to the Tier 1 Calculation Methodology for stationary combustion sources in §98.33(a)(1). A higher tier from §98.33(a) may be used to
calculate fossil fuel

- based CO 2 emissions if the respective monitoring and QA/QC req uirements described in §98.34

are met. (1) Calculate fossil CO 2 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 § 98.33(a)(1). Tiers 2 or 3 from § 98.33(a)(2) or (3) may be
used to calculate fossil fuel

- based CO 2 emissions if the respective monitoring and QA/QC requirements described in
§ 98.34 are met. See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

AA 98.273(c)(1) (1) Calculate CO 2 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 §98.33(a)(1). A higher tier from § 98.33(a) may
be used to calculate fossil fuel

- based CO 2 emissions if the respective monitoring and QA/QC requirements described
in §98.34 are met. (1) Calculate CO 2 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 § 98.33(a)(1). Tiers 2 or 3 from § 98.33(a)(2) or (3) may be
used to calculate fossil fuel

- based CO 2 emissions if the respective monitoring and QA/QC requirements described in
§ 98.34 are met. See preamble text for explanation.

AA 98.275(b) (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. (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 § 63.866(c)(1) may be used, adjusting for the duration of the missing measurements, as appropriate. See preamble text for explanation.

AA Table AA

- 2 Table AA

- 2 See Appendix A for changes to Table AA

- 2 See preamble text for explanation.

CC 98.294(a)(2) (2) Measure the mass of trona input produced by each soda ash manufacturing line on a monthly basis using belt scales or methods used for accounting purposes. (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. Edito rial correction.

CC 98.296(a)(1) (1) Annual consumption of trona or liquid alkaline feedstock for each manufacturing line (tons). (1) Annual consumption of trona or liquid alkaline feedstock at the facility level (tons). See preamble text for explanation.

CC 98.296(b)(5) [Reserved] (5) Annual consumption of trona or liquid alkaline feedstock at the facility level (tons). See preamble text for explanation.

DD 98.306(a) (2) New during the year (all SF6

- insulated equipment, including hermetically sealed

- pressure switchgear). (3) Retired during the year (all SF6

- insulated equipment, including hermetically sealed

- pressure switchgear). (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. See preamble text for explanation.

DD 98.306(m) None (m) State(s) or territory in which the facility lies and total
miles of transmission and distribution lines located within each state or territory

. See preamble text for explanation.

DD 98.306(n) None (n) The following numbers of pieces of equipment: See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change (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 switchge ar during the year. (4) Retired SF6

- or PFC

- insulated equipment other than hermetically sealed

- pressure switchgear during the year.

FF 98.323(a) (a) For each ventilation shaft, vent hole, or centralized point into which CH 4 from multiple shafts and/or vent holes are collected, you must calculate the quarterly CH 4 liberated from the ventilation system using Equation FF

- 1
of this section. You must measure CH 4 content, flow rate, temperature, pressure, and moisture content of the gas using the procedures outlined in §98.324.

Where: CH4V = Quarterly CH4 liberated from a ventilation monitoring point (metric tons CH 4 ). V = Volumetric flow rate for the quarter (acfm) based on sampling or a flow rate meter. If a flow rate mete r is used and the meter automatically corrects to standard temperature and pressure, then use scfm and replace “520°R/T × P/1 atm” with “1”.
MCF = Moisture correction factor for the measurement period, volumetric basis.
= 1 when V and C are measured on a d ry basis or if both are
measured on a wet basis.

= 1

- (fH2O) when V is measured on a wet basis and C is measured on a dry basis. = 1/[1

- (fH2O)] when V is measured on a dry basis and C is
measured on a wet basis. (fH2O) = Moisture content of the CH 4 emitted during the measurement period, volumetric basis (cubic feet water per cubic feet emitted gas). C = CH4 concentration of ventilation gas for the quarter (%). (a) For each ventilation shaft, vent hole, or centralized poin t into which CH 4 from multiple shafts and/or vent holes are collected, you must calculate the quarterly CH 4 liberated from the ventilation system using Equation FF

- 1 of this

section. You must measure CH 4 content, flow rate, temperature, pressure, and moist ure content of the gas using the procedures outlined in §98.324.

Where: CH4V = Quarterly CH4 liberated from a ventilation monitoring point (metric tons CH 4 ). V = Volumetric flow rate for the quarter (acfm) based on sampling or a flow rate meter. If a fl ow rate meter is used and the meter automatically corrects to standard temperature and pressure, then use scfm and replace “520°R/T × P/1 atm” with “1”.
MCF = Moisture correction factor for the measurement period, volumetric basis.
= 1 when V and C are mea sured on a dry basis or if both are
measured on a wet basis.

= 1

- (fH2O) when V is measured on a wet basis and C is measured on a dry basis. = 1/[1

- (fH2O)] when V is measured on a dry basis and C is
measured on a wet basis. (fH2O) = Moisture content of the CH 4 emitted during the measurement period, volumetric basis (cubic feet water per cubic feet emitted gas). C = CH4 concentration of ventilation gas for the quarter (%).

n = The number of days in the quarter where active ventilation of mining operations is taking place at the See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change n = The number of days in the quarter where active ventilation of mining operations is taking place at the monitoring point. 0.0423 = Density of CH 4 at 520 °R (60 °F) and 1 atm (lb/scf). 520 °R = 520 degrees Rankine. T = Temperature at which flow is measured (°R) for the
quarter. P = Absolute pressure at which flow is measured (atm) for the quarter. The annual average barometric pressure from the nearest NOAA weather service station may be used as a
default. 1,440 = Conversion factor (min/day). 0.454/1,000 = Conversion factor (metric ton/lb). 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. 0.0423 = Density of CH 4 at 520 °R (60 °F) and 1 atm (lb/scf).

5 20 °R = 520 degrees Rankine. T = Temperature at which flow is measured (°R) for the
quarter. P = Absolute pressure at which flow is measured (atm) for the quarter. The annual average barometric pressure from the nearest NOAA weather service station may be used as a
default. 1,440 = Conversion factor (min/day). 0.454/1,000 = Conversion factor (metric ton/lb).

FF 98.323(a)(1) and (2) (1) Consistent with MSHA inspections, the quarterly periods are: (i) January 1

- March 31. (ii) April 1

- June 30. (iii) July 1

- September 30. (iv) October 1

- December 31. (2) Values of V, C, T, P, and (fH2O), if applicable, must be based on measurements taken at least once each quarter
with no fewer than 6 weeks between measurements. If

measurement s are taken more frequently than once per quarter, then use the average value for all measurements taken. If continuous measurements are taken, then use the average value over the time period of continuous monitoring. (1) The quarterly periods are: (i) January 1

- March 31. (ii) April 1

- June 30. (iii) July 1

- September 30. (iv) October 1

- December 31. (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 measur ements. If measurements are taken more frequently than once per
quarter , then use the average value for all measurements taken. If continuous measurements are taken, then use the average value over the time period of continuous monitoring. See preamble te xt for explanation.

FF 98.323(b); Equation FF

- 3 CH 4 D = Weekly CH 4 liberated from at the monitoring point (metric tons CH 4 ). CH 4 D = Weekly CH 4 liberated from the monitoring point (metric tons CH 4 ). See preamble text for explanation.

FF 98.323(b); Equation FF

- 3 n = The number of days in the week that the system is operational at that measurement point. n = The number of days in the week that the system is operational at that measurement point. To obtain the number of days in the week, divide the to tal number of hours that the system is operational by 24 hours per day. See preamble text for explanation.

FF 98.323(b)(1) and (2) (1) Values for V, C, T, P, and (fH2O), if applicable, must be
based on measurements taken at least once each calendar (1) Values for V, C, T, P, and, if applicable, (fH2O), must be
based on measurements taken at least once each calendar See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

week with at least 3 days between measurements. If measurements are taken more frequently than once per week, then use the average value for all measurements taken that week. If continuous measurements are taken, then use the average values over the time period of continuous monitoring when the continuous monitoring equipment is properly functioning. (2) Quarterly total CH 4 liberated from degasification systems for the mine should be determined as the sum of

CH 4 liberated determined at each of the monitoring points in the mine, summed over the number of weeks in the quarter, as follows: week with at least 3 days between measurements. If measurements are taken more frequently than once per week, then use the average value for all measurements taken that week. If continuous measurements are taken, then use the average values over the time period of continuous monitoring when the continuous monitoring equipment is properly functioning. (2) Quarterly total CH4 liberated from degasification systems
for the mine must be determined as the sum of CH 4 liberated determined at each of the monitoring points in the mine, summed over the number of weeks in the quarter, as
follows:

FF 98.324(b)(1) (b)(1) Collect quarterly or more frequent grab samples (with no fewer than 6 weeks between measurements) for
methane concentration a nd make quarterly measurements of flow rate, temperature, pressure, and moisture content, if applicable. The sampling and measurements must be made at the same locations as Mine Safety and Health Administration (MSHA) inspection samples are taken, and
shou ld be taken when the mine is operating under normal conditions. You must follow MSHA sampling procedures as set forth in the MSHA Handbook entitled, General Coal Mine Inspection Procedures and Inspection Tracking System Handbook Number: PH

- 08

- V

- 1, January 1, 2008 (incorporated by reference, see §98.7). You must record the date of sampling, flow, temperature, pressure, and moisture measurements, the methane concentration (percent), the bottle number of samples collected, and the
location of the measurement o r collection. (1) Collect quarterly or more frequent grab samples (with no fewer than 6 weeks between measurements) for methane concentration and make quarterly measurements of flow rate, temperature, pressure, and, if applicable, moisture
content. The sam pling and measurements must be made at the same locations as Mine Safety and Health Administration (MSHA) inspection samples are taken, and should be taken when the mine is operating under normal conditions. You must follow MSHA sampling procedures as set forth in the MSHA Handbook entitled, Coal Mine Safety and Health General Inspection Procedures Handbook Number: PH

- 13

- V

1, February 2013 (incorporated by reference, see § 98.7). You must record the date of sampling, flow, temperature, pressure, and moistur e measurements, the methane

concentration (percent), the bottle number of samples collected, and the location of the measurement or
collection. See preamble text for explanation.

FF 98.324(b)(2) (2) Obtain results of the quarterly (or more frequent) testing performed by MSHA for the methane flowrate. At the same location and within seven days of the MSHA sampling, make measurements of temperature and pressure using the same procedures specified in paragraph (b)(1) of this section. The annual average barometric pressure from the nearest National Oceanic and Atmospheric Administration (NOAA) weather service (2) [ Reserved ] See preamble text for explanation.

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### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change station may be used as a default for pressure. If the MSHA data for methane flow is provided i n the units of actual cubic feet of methane per day, the methane flow data is inserted into Equation FF

- 1 of this section in place of the value for V and the variables MCF, C/100%, and 1440 are removed from the equation.

FF 98.324(h) (h) If applicable, the owner or operator shall document the procedures used to ensure the accuracy of gas flow rate, gas composition, temperature, pressure, and moisture content measurements. These procedures include, but are not limited to, calibration of flow meters, and other measurement devices. The estimated accuracy of measurements, and the technical basis for the estimated accuracy shall be recorded. (h) The owner or operator shall document the procedures
used to ensure the accuracy of gas flow rate, gas composition, temperature, pressure, and moisture content measurements. These procedures include, but are not limited to, calibration of flow meters, and other
measurement devices. The estimated accuracy of
measurements, and the technical basis for the estimated accuracy shall be recorded. See preamble text for explanation.

FF 98.326(f) through (i) (f) Quarterly volumetric flow rate for each ventilation monitoring point and units of measure (scfm or acfm), date
and location of each measurement, and method of measurement (quarterly sampling or continuous monitoring), used in Equation FF

- 1 of this subpart. (g) Quarterly CH 4 concentration for each ventilation monitoring point, dates and locations of each
measurement and method of measurement (sampling or continuous monitoring). (h) Weekly volumetric flow rate used to calculate CH 4 liberated from degasification systems and units of measure (acfm or scfm), and method of measurement (sampling or continuous monitoring), used in Equation FF

- 3 of this subpart. (i) Quarterly CH 4 concentration (%) used to calculate CH4 liberated from degasification systems and if the data is based on CEMS or weekly sampling. (f) Quarterly volumetric flow rate for each ventilation monitoring point and units of measure (scfm or acfm), date and location of each measurement, and method of measurement ( q uarterly sampling or continuous monitoring), used in Equation FF

- 1 of this subpart. Specify
whether the volumetric flow rate measurement at each ventilation monitoring point is on dry basis or wet basis; or, if a flow meter is used, indicate whether or not the flo w meter automatically corrects for moisture content. (g) Quarterly CH 4 concentration for each ventilation monitoring point, dates and locations of each measurement, and method of measurement (sampling or continuous monitoring). Specify whether the CH 4 conc entration measurement at each ventilation monitoring point is on dry
basis or wet basis. (h) Weekly volumetric flow rate used to calculate CH 4 liberated from degasification systems and units of measure (acfm or scfm), and method of measurement (sampling or continuous monitoring), used in Equation FF

- 3 of this subpart. Specify whether the volumetric flow rate measurement at each degasification monitoring point is on dry basis or wet basis; or, if a flow meter is used, indicate
whether or not the flow meter a utomatically corrects for

moisture content. See preamble text for explanation.

### 39 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change (i) Quarterly CH 4 concentration (%) used to calculate CH 4 liberated from degasification systems, and if the data is based on CEMS or weekly sampling. Specify whether the CH 4 concentration measurement at each dega sification monitoring point is on dry basis or wet basis

.

FF 98.326(o) (o) Temperatures (°R), pressure (atm), moisture content, and the moisture correction factor (if applicable) used in Equation FF

- 1 and FF

- 3 of this subpart; and the gaseous organic concentration correction factor, if Equation FF

- 9 was required. (o) Temperature (°R), pressure (atm), moisture content (if applicable), and the moisture correction factor (if applicable) used in Equations FF

- 1 and FF

- 3 of t his subpart; and the gaseous organic concentration correction factor, if Equation

FF

- 9 was required. Moisture content is required to be reported only if CH 4 concentration is measured on a wet basis and volumetric flow is measured on a dry basis, if CH 4

co ncentration is measured on a dry basis and volumetric flow is measured on a wet basis; or, if a flow meter is used, the flow meter does not automatically correct for moisture

content. See preamble text for explanation.

FF 98.326(r)(2) and (3) (2) Start date and close date of each well, shaft, and vent
hole. (3) Number of days the well, shaft, or vent hole was in operation during the reporting year. (2) Start date and close date of each well, shaft, and vent hole. If the well, shaft, or vent hole is ope rating through the end of the reporting year, December 31st of the reporting year shall be the close date for purposes of reporting. (3) Number of days the well, shaft, or vent hole was in operation during the reporting year. To obtain the number of day s in the reporting year, divide the total number of hours that the system was in operation by 24 hours per day. See preamble text for explanation.

FF 98.326(u) None (u) Annual coal production in short tons for the reporting

year. See preamble text for explanation.

HH 98.346(f) The surface area of the landfill containing waste (in square meters), identification of the type of cover material used (as either organic cover, clay cover, sand cover, or other soil mixtures). If multiple cover types are used, the surface area associated with each cover type. (f) The surface area of the landfill containing waste (in square meters), identification of the type(s) of cover material used (as either organic cover, clay cover, sand cover, or other soil mixtures). See preamble text for explanation.

HH 98.346(i)(5) (5) An indication of whether destruction occurs at the landfill facility, off

- site, or both. If destruction occurs at the landfill facility, also report for each measurement location
the number of destruction devices associated with that
measurement locati on and the annual operating hours and (5) An indication of whether destruction occurs at the landfill facility, off

- site, or both. If destruction oc curs at the landfill facility, also report for each measurement location: (i) The number of destruction devices associated with the
measurement location. See preamble text for explanation.

### 40 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change the destruction efficiency (percent) for each destruction
device associated with that measurement location. (ii) The annual operating hours of the gas collection system associated with the measurement location, (iii) For each destruction device associated with the measurement location, report: (A) The destruction efficiency (decimal). (B) The annual operating hours where active gas flow was
sent to the destruction device.

HH 98.346(i)(7) (7) A description of the gas collection system (manufacturer, capacity, and number of wells), the surface area (square meters) and estimated waste depth (meters) for each area specified in Table HH

- 3 to this subpart, the estimated gas collecti on system efficiency for landfills with this gas collection system, the annual operating hours of the gas collection system for each measurement location, and an indication of whether passive vents and/or passive flares (vents or flares that are not consid ered part of the gas collection system as defined in §98.6) are present at
the landfill. (7) A description of the gas collection system (manufacturer, capacity, and number of wells), the surface area (square meters) and estimated waste depth (meters) for e ach area specified in Table HH

- 3 to this subpart, the estimated gas collection system efficiency for landfills with this gas collection system and an indication of whether the gas collection efficiency was determined on an area

- weighted average basis (Opti on 1) or a volume

- weighted average basis (Option 2), and an indication of whether passive vents and/or passive flares (vents or flares that are not considered part of the gas collection system as defined in § 98.6) are present at the landfill. Harmonizes w ith proposed changes to
Table HH

- 3.

HH 98.346(i)(13) None (13) Methane emissions for the landfill (i.e., the subpart HH total methane emissions). Choose the methane emissions from either Equation HH

- 6 of this subpart or Equation HH

- 8 of this subpart that best represents the emissions from the landfill. If the quantity of recovered CH4 from Equation HH

- 4 of this subpart is used as the value of GCH 4 in Equation HH

- 6 of this subpart, use the methane emissions calculated using Equation HH

- 8 of this subpart as the methane emissions for
the landfill. See preamble text for explanation.

HH 98.348 None Active venting means a pipe or a system of pipes used with a fan or similar mechanical draft equipment (forced convection) used to actively assist the flow of landfill gas to the surface of the landfill where the landfill gas is discharged either directly to the atmosph ere or to a non

- combustion control device (such as a carbon absorber) and then to the atmosphere. See preamble text for explanation.

HH 98.348 None Alternative final cover means materials, other than soil, used at a landfill that meets final closure regulations of the competent federal, state, or local authority. Alternative final See preamble text for explanation.

### 41 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change covers may include, but are not limited to, evapotranspiration covers, capillary barrier cover s, asphalt covers, or concrete covers. The state, local, or other agency responsible for permitting the landfill determines whether an alternative final cover meets the applicable regulatory requirements and has been shown to adequately protect
human heal th and the environment.

HH 98.348 None Intermediate or interim cover means the placement of material over waste in a landfill for a period of time prior to the disposal of additional waste and/or final closure as defined by state regulation, permit, guidance or written plan, or state accepted best management practice. S ee preamble text for explanation.

HH 98.348 None Passive vent means a pipe or a system of pipes that allows landfill gas to flow naturally, without the use of a fan or similar mechanical draft equipment, to the surface of the landfill where an opening or pipe (vent) allows for the free flow of landfill gas to the at mosphere or to a passive vent flare without diffusion through the top layer of surface soil. See preamble text for explanation.

HH Table HH

- 3 Table HH

- 3 See Appendix A for changes to Table HH

- 3 See preamble text for explanation.

HH Table HH

- 4 Table HH

- 4 See Appendix A for changes to Table HH

- 4 See preamble text for explanation.

II 98.356(a) (a) A description or diagram of the industrial wastewater treatment system, identifying the processes used to treat
industrial wastewater and industrial wastewater tr eatment sludge. Indicate how the processes are related to each other and identify the anaerobic processes. Provide a unique identifier for each anaerobic process, indicate the average depth in meters of each anaerobic lagoon, and indicate whether biogas ge nerated by each anaerobic process is recovered. The anaerobic processes must be
identified as: (1) Anaerobic reactor. (2) Anaerobic deep lagoon (depth more than 2 meters). (3) Anaerobic shallow lagoon (depth less than 2 meters). (4) Anaerobic sludge digest er. (a) Identify the anaerobic processes used in the industrial wastewater treatment system to treat industrial wastewater and industrial wastewater treatment sludge, provide a unique identifier for each anaerobic process, indicate the average depth in meters of each anaerobic lagoon, and indicate whether biogas generated by each anaerobic process is recovered. Provide a description or diagram of the industrial wastewater treatment system, identifying the processes used, indicating how the processes are related to each other, and providing a unique identifier for each anaerobic process. Each anaerobic processes must be identified as one of the following: (1) Anaerobic reactor. (2) Anaerobic deep lagoon (depth more than 2 meters). (3) Anaerobic shallow lag oon (depth less than 2 meters). (4) Anaerobic sludge digester. Clarifies reporting requirements.

### 42 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

II 98.356(b)(6) None (6) If the facility performs an ethanol production processing operation as defined in § 98.358 of this subpart, you must
indicate if the facility uses a wet milling process or a dry milling process. See preamble text for explanation.

II 98.358 None Dry milling means the process in which shelled corn is milled by dry process, without an initial steeping step. Harmonizing change
with proposed 40 CFR 98.356(b)(6).

II 98.358 None Wet milling means the process in which shelled corn is steeped in a dilute solution of sulfurous acid (sulfur dioxide dissolved in water) prior to further processing. Harmonizing change with proposed 40 CFR

98. 356(b)(6).

II 98.358 None Weekly average means the sum of all values measured in a calendar week divided by the number of measurements. See preamble text for explanation.

LL 98.382 You must report the CO 2 emissions that would result from the complete combustion or oxidation of fossil

- fuel products (besides coal or crude oil) that you produce, use as feedstock, import, or export during the calendar year. Additionally, producers must report CO 2 emissions tha t would result from the complete combustion or oxidation of any biomass co

- processed with fossil fuel

- based feedstocks. Suppliers of coal

- based liquid fuels must report the CO 2 emissions that would result from the complete combustion
or oxidation of fossil

- fuel products (besides coal or crude oil) produced, used as feedstock, imported, or exported during the calendar year. Additionally, producers must report CO 2 emissions that would result from the complete combustion or oxidation of any biomass co

- processe d with fossil fuel

based feedstocks. Clarifies definition of
"You" and harmonizes language with subpart

MM.

LL 98.383 You must follow the calculation methodologies of §98.393 as if they applied to the appropriate coal

- to

- liquid product supplier (i.e., calculation methodologies for refiners apply to producers of coal

- to

- liquid products and calculation methodologies for importers and exporters of petroleum products apply to importers and exporters of coal

- to

- liquid products). Suppliers of coal

- based liqui d fuels must follow the calculation methods of § 98.393 as if they applied to the appropriate coal

- to

- liquid product supplier (i.e., calculation methods for refiners apply to producers of coal

- to

- liquid products and calculation methods for importers and

ex porters of petroleum products apply to importers and exporters of coal

- to

- liquid products). Clarifies definition of
"You" and harmonizes language with subpart

MM.

LL 98.383(a) through (c ) (a) In calculation methodologies in §98.393 for petroleum products or petroleum

- based products, suppliers of coal

to

- liquid products shall also include coal

- to

- liquid products. (b) In calculation methodologies in §98.393 for non

- crude
feedstocks or non

- crude petroleum feedstocks, producers
of coal

- to

- liquid products shal l also include coal

- to

- liquid products that enter the facility to be further processed or
otherwise used on site. (c) In calculation methodologies in §98.393 for petroleum feedstocks, suppliers of coal

- to

- liquid products shall also (a) In calculation methods in § 98.393 for petroleum products or petroleum

- based products, suppliers of coal

- to

liquid products shall also include coal

- to

- liquid pr oducts. (b) In calculation methods in § 98.393 for non

- crude
feedstocks or non

- crude petroleum feedstocks, producers of
coal

- to

- liquid products shall also include coal

- to

- liquid products that enter the facility to be further processed or
otherwise used on site. (c) In calculation methods in § 98.393 for petroleum feedstocks, suppliers of coal

- to

- liquid products shall also Harmonizes language

w ith subpart MM.

### 43 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

include coal and coal

- to

- liquid products that enter the facility to be further processed or otherwise used on site. include coal and coal

- to

- liquid products that enter the facility to be further processed or otherwise used on site.

LL 98.384 You must follow the monitoring and QA/QC requirements in §98.394 as if they applied to the appropriate coal

- to

liquid product supplier. Any monitoring and QA/QC requirement for petroleum products in §98.394 also applies to coal

- to

- liquid products. Suppliers of coal

- based liquid fuels must follow the monitoring and QA/QC requirements in § 98.394 as if they applied to the appropriate coal

- to

- liquid product supplier. Any monitoring and QA/QC requirement for petroleum products i n § 98.394 also applies to coal

- to

- liquid products. Clarifies definition of
"You" and harmonizes language with subpart

MM.

LL 98.385 You must follow the procedures for estimating missing data in §98.395 as if they applied to the appropriate coal

- to

liquid product supplier. Any procedure for estimating missing data for petroleum products in §98.395 also applies
to coal

- to

- liquid products. Suppliers of coal

- based liquid fuels must follow the procedures for estimating missing data in § 98.395 as if they appli ed to the appropriate coal

- to

- liquid product supplier. Any procedure for estimating missing data for petroleum products in § 98.395 also applies to coal

- to

- liquid products. Clarifies definition of
"You" and harmonizes language with subpart

MM.

LL 98.386(a )(4) (4) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (a)(2) of this section. [Reserved] See preamble text for explanation.

LL 98.386(a)(8) (8) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (a)(6) of this section. [Reserved] See preamble text for explanation.

LL 98.386(a)(9) (9) For every feedstock reported in paragraph (a)(2) of this section for which Calculation Methodology 2 of subpart MM of this part was used to determine an emissions factor,
report: ... (9) For every feedstock reported in paragraph (a)(2) of this section for which Calculation Method 2 of subpart MM of this part was used to determine an emissions factor, report:

... Harmonizes language with subpart MM.

LL 98.386(a)(10) (10) For every non

- solid feedstock reported in paragraph (a)(2) of this section for which Calculation Methodology 2 of subpart MM of this part was used to determine an emissions factor, report: ... (10) For every non

- solid feedstock reported in paragraph (a)(2) of this section for which Calculation Method 2 of subpart MM of this part was used to determine an emissions factor, report: ... Harmonizes language with subpart MM.

LL 98.386(a)(11) (11) For e very product reported in paragraph (a)(6) of this section for which Calculation Methodology 2 of this subpart was used to determine an emissions factor, report: ... (11) For every product reported in paragraph (a)(6) of this
section for which Calculation Met hod 2 of this subpart was used to determine an emissions factor, report: ... Harmonizes language with subpart MM.

LL 98.386(a)(15) (15) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (a)(14) of this section. [Reserved] See preamble text for explanation.

LL 98.386(a)(20) (20) Annual quantity of bulk NGLs in metric tons or barrels received for processing during the reporting year. (20) Annual quantity of bulk NGLs in metric tons or barrels

receive d for processing during the reporting year. Report only quantities of bulk NGLs not reported in (a)(2) of this

section. See preamble text for explanation.

### 44 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

LL 98.386(b)(4) (4) Each standard method or other industry standard practice used to measure each quantity reported in paragraph (b)(2) of this section. [Reserved] See preamble text for explanation.

LL 98.386(b)(5) (5) For each product reported in paragraph (b)(2) of this section for which Calculation Methodology 2 of this subpart
used was used to det ermine an emissions factor, report: (5) For each product reported in paragraph (b)(2) of this section for which Calculation Method 2 of this subpart used was used to determine an emissions factor, report: Harmonizes language with subpart MM.

LL 98.386(b)( 6) (6) For each non

- solid product reported in paragraph (b)(2) of this section for which Calculation Methodology 2 of this subpart was used to determine an emissions factor, report: (6) For each non

- solid product reported in paragraph (b)(2)
of this section for which Calculation Method 2 of this subpart was used to determine an emissions factor, report: Harmonizes language with subpart MM.

LL 98.386(c)(4) (4) Each standard method or other industry standard practice used to measure each quantity repor ted in paragraph (c)(2) of this section. [Reserved] See preamble text for explanation.

LL 98.386(c)(5) (5) For each product reported in paragraph (c)(2) of this section for which Calculation Methodology 2 of this subpart
was used to determine an emissions factor, report: (5) For each product reported in paragraph (c)(2) of this section for which Calculation Method 2 of this subpart was used to determine an emissions factor, report: Harmonizes language with subpart MM.

LL 98.386(c)(6) (6) For each non

- solid product reported in paragraph (c)(2) of this section for which Calculation Methodology 2 of this subpart used was used to determine an emissions factor,
report: (6) For each non

- solid product reported in paragraph (c)(2)
of this section for which Calculation Method 2 of this subpart used was used to determine an emissions factor,
report: Harmonizes language with subpart MM.

LL 98.387 You must retain records according to the requirements in §98.397 as if they applied to the appropriate coal

- to

- liq uid product supplier (e.g., retaining copies of all reports submitted to EPA under §98.386 and records to support information contained in those reports). Any records for petroleum products that are required to be retained in §98.397 are also required for coal

- to

- liquid products. Suppliers of coal

- based liquid fuels must retain records according to the requirements in § 98.397 as if they applied to the appropriate coal

- to

- liquid product supplier (e.g., retaining copies of all reports submitted to EPA under § 98.386 and records to support information contained in those reports). Any records for petroleum products that are required to be retained in § 98.397 are also required for
coal

- to

- liquid products. Clarifies definition of
"You" and harmonizes language w ith subpart

MM.

MM 98.395(c) (c) Determination of API gravity and sulfur content of crude oil. For missing data on sulfur content or API gravity, the substitute data value shall be the arithmetic average of the quality

- assured values of API gravity or sulfur content in the batch preceding and the batch immediately following the missing data incident. If no quality

- assured data are available prior to the missing data incident, the substitute data value shall be the first quality

- assured values for API

gr avity and sulfur content obtained from the batch after the missing data period. None Corrections for consistency with
revisions from 78 FR 71904 (November 29, 2013) that removed the requirement to measure API gravity and the sulfur
content of each batch of
crude oil.

### 45 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

NN 98.401 Any supplier of natural gas and natural gas liquids that meets the requirements of §98.2(a)(4) must report GHG

emissions. Any supplier of natural gas and natural gas liquids that meets the requirements of § 98.2(a)(4) must report GHG emissions associated with the products they supply. Clarifies requirement.

NN 98.403(a)(1) (1) Calculation Methodology 1. NGL fractionators shall
estimate CO2 emissions that would result from the complete combustion or oxidation of the product(s) supplied using Equation NN

- 1 of this section. LDCs shall

estimate CO 2 emissions that would result from the complete combustion or oxidation of the product received at the city gate using Equation NN

- 1. (1) Calculation Methodology 1. NGL fractionators shal l

estimate CO 2 emissions that would result from the complete combustion or oxidation of the product(s) supplied using Equation NN

- 1 of this section. The annual volume of each NGL product supplied (Fuelh) shall include any amount of that NGL supplied in a m ixture or blend of two or more products listed in Tables NN

- 1 and NN

- 2 of this subpart. The annual volume of each NGL product supplied shall exclude any amount of that NGL contained in bulk NGLs exiting the facility not fractionated by the reporter (e.g., y

- grade, o

grade, and other bulk NGLs). LDCs shall estimate CO 2 emissions that would result from the complete combustion or oxidation of the natural gas received at the city gate (including natural gas that is transported by, but not owned by, the reporter ) using Equation NN

- 1 of this section. ... Clarifies when an NGL fractionator must report a product supplied when it is part of a mixture,
and that LDCs must report gas supplied that
the LDC does not "own".

NN 98.403(a)(1); Equation NN

1 CO 2. = Annual CO2 mass emissions that would result from the combustion or oxidation of each product “h” for redelivery to all recipients (metric tons). CO 2i = Annual CO2 mass emissions that would result from the combustion or oxidation of each product “h” for redelivery to all recipients (metric tons). Editorial correction.

NN 98.403(a)(2) (2) Calculation Methodology 2. NGL fractionators shall

estimate CO 2 emissions that would result from the complete combustion or oxidation of the product(s) supplied using Equation NN

- 2 o f this section. LDCs shall

estimate CO 2 emissions that would result from the complete combustion or oxidation of the product received at the city gate using Equation NN

- 2. (2) Calculation Methodology 2. NGL fractionators shall

estimate CO 2 emissions that would result from the complete combustion or oxidation of the product(s) supplied using Equation NN

- 2 of this section. The annual volume of each NGL product supplied (Fuelh) shall include any amount of that NGL supplied in a mixture or blend of two or more products listed in Tables NN

- 1 and NN

- 2 of this subpart. The annual volume of each NGL product supplied shall exclude any amount of that NGL contained in bulk NGLs exiting the facility not fractionated by the reporter (e.g., y

- grade, o

grade, and other bu lk NGLs). LDCs shall estimate CO 2 emissions that would result from the complete combustion or oxidation of the natural gas received at the city gate (including natural gas that is transported by, but not owned by, the reporter) using Equation NN

- 2 of this section. ... Clarifies when an NGL fractionator must report a product supplied when it is part of a mixture,
and that LDCs must report gas supplied that
the LDC does not "own".

### 46 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

NN 98.403(a)(2); Equation NN

2 CO 2. = Annual CO2 mass emissions that would result from the combustion or oxidation of each product “h” (metric tons) CO 2 i = Annual CO2 mass emissions that would result from the combustion or oxidation of each product “h” (metric tons) Editorial correction.

NN 98.403(b)(1); Equation NN

3 CO 2. = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas for redelivery to transmission pipelines or other LDCs (metric tons). CO 2j = Annual CO 2 mass emissions that would result from the
combustion or oxidation of natu ral gas for redelivery to transmission pipelines or other LDCs (metric tons). Editorial correction.

NN 98.403(b)(1); Equation NN

3 Fuel = Total annual volume of natural gas supplied (Mscf per year). Fuel = Total annual volume of natural gas supplied to downstream gas transmission pipelines and other local distribution companies (Mscf per year). Clarifies equation term.

NN 98.403(b)(2)(ii ); Equation

NN

- 4 CO 2 . = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas de livered to each large end

- user k, as defined in paragraph (b)(2)(i) of this section (metric tons). CO 2k = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas delivered to each large end

- user k, as defined in paragrap h (b)(2)(i) of this section (metric tons). Editorial correction.

NN 98.403(b)(3)(i ); Equation

NN

- 5a CO 2 . = Annual CO 2 mass emissions that would result from the combustion or oxidation of the net change in natural gas stored on system by the LDC within the reporting year (metric tons). CO 2l = Annual CO 2 mass emissions that would result from the
combustion or oxidation of the net change in natural gas stored on system by the LDC within the reporting year (metric tons). Editorial correction.

NN 98.403(b)(3)(i ); Equation

NN

- 5a EF = Annual average CO 2 emission factor for natural gas placed into/removed from storage (MT CO 2 /Mscf). EF = CO 2 emission factor for natural gas placed into/removed from storage (MT CO 2 /Mscf). Clarifies equation term.

NN 98.403(b)(3)(ii ); Equation

NN

- 5b CO 2 . = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas received that bypassed the city gate and is not otherwise accounted for by Equation NN

- 1 or NN

- 2 of this section (metric tons). CO 2n = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas received that bypassed the city gate and is not otherwise accounted for by Equation NN

- 1 or NN

- 2 of this section (metric tons). Editorial correction.

NN 98.403(b)(4); Equation NN

6 CO 2 . = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas received at the city gate as calculated in paragraph (a)(1) or (2) of this section (metric tons).

CO 2 . = Annual CO 2 mass emissions that would r esult from the combustion or oxidation of natural gas delivered to transmission pipelines or other LDCs as calculated in paragraph (b)(1) of this section (metric tons).

CO 2 . = Annual CO 2 mass emissions that would result from
the combustion or oxidation of natural gas delivered to each large end

- user as calculated in paragraph (b)(2) of this section (metric tons).

CO 2 . = Annual CO 2 mass emissions that would result from the combustion or oxidation of the net change in natural CO 2i = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas received a t the city gate as calculated in paragraph (a)(1) or (2) of this section (metric tons).

CO 2j = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas delivered to transmission pipelines or other LDCs as calculated in

pa ragraph (b)(1) of this section (metric tons).

CO 2k = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas delivered to each large end

- user as calculated in paragraph (b)(2) of this section (metric tons).

CO 2l = Annual CO 2 mass emissions that would result from the combustion or oxidation of the net change in natural gas Editorial corrections.

### 47 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change gas stored by the LDC within the reported year as calculated in paragraph (b)(3)(i) of this section (metric tons).

CO 2 . = Annual CO 2 mass emissions that would result from the combustion or oxidation of natural gas that was received by the LDC directly from sources bypassing the city gate, and is not otherwise accounted for in Equation

NN

- 1 or NN

- 2 of this section, as calculated in paragraph (b)(3)(ii) of this section (metric tons). stored by the LDC within the reported year as calculated in paragraph (b)(3)(i) of this section (metric tons).

CO 2n = Annual CO2 mass emissions that wou ld result from the combustion or oxidation of natural gas that was received by the LDC directly from sources bypassing the city gate, and is not otherwise accounted for in Equation NN

- 1 or NN

- 2 of this section, as calculated in paragraph (b)(3)(ii) of this section (metric tons).

NN 98.403(c)(1)(ii ); Equation

NN

- 7 CO 2. = Annual CO2 mass emissions that would result from
the combustion or oxidation of each fractionated NGL product “g” received from other fractionators (metric tons). CO 2m = Annual CO2 mass emissions that would result from
the combustion or oxidation of each fractionated NGL product “g” received from other fractionators (metric tons). Editorial correction.

NN 98.403(c)(1)(ii ); Equation

NN

- 7 Fuelg = Total annual volume of each NGL product “g” received (bbls). Fuelg = Total annual volume of each NGL product “g” received from other fractionators (bbls). Clarifies equation term
to reduce confusion over reporting of NGL
received vs. bulk NGL
received.

NN 98.403(c)(2); Equatio n NN

8 CO 2. = Annual CO2 mass emissions that would result from
the combustion or oxidation of fractionated NGLs delivered
to all customers or on behalf of customers as calculated in paragraph (a)(1) or (a)(2) of this section (metric tons). CO 2i = Annual CO2 mass emissions that would result from
the combustion or oxidation of fractionated NGLs delivered
to all customers or on behalf of customers as calculated in paragraph (a)(1) or (a)(2) of this section (metric tons). Editorial correction.

NN 98.403(c)(2); Equation NN

8 CO 2. = Annual CO2 mass emissions that would result from
the combustion or oxidation of fractionated NGLs received from other fractionators and calculated in paragraph (c)(1) of this section (metric tons). CO 2m = Annual CO2 mass emissions that would result from
the combustion or oxidation of fractionated NGLs received from other fractionators and calculated in paragraph (c)(1) of this section (metric tons). Editorial correction.

NN 98.404(a)(1) (a) Determination of quantity. (1) NGL fractionators and LDCs shall determine the quantity of NGLs and natural gas using methods in common use in the industry for billing purposes as audited under existing Sarbanes Oxley regulation. (a) Determination of quantity. (1) NGL fractionators and

L DCs shall determine the quantity of NGLs and natural gas using methods in common use in the industry for billing purposes as audited under existing Sarbanes Oxley regulation. Editorial correction.

NN 98.404(a)(3) (3) NGL fractionators shall use measu remen t for NGLs at custody tran fer meters or at such meters that are used to determine the NGL product slate delivered from the fractionation facility. (3) NGL fractionators shall use measurement for NGLs at custody transfer meters or at such meters that are used to determine the NGL product slate delivered from the fractionation facility. Editorial correction.

NN 98.404(a)(4) (4) If a NGL fractionator supplies a product not listed in
Table NN

- 1 of this subpart that is a mixture or blend of two or more produc ts listed in Tables NN

- 1 and NN

- 2 of this (4) If a NGL fractionator supplies a product that is a mixture or blend of two or more products li sted in Tables NN

- 1 and

NN

- 2 of this subpart, the NGL fractionator shall report the Editorial correction.

### 48 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change subpart, the NGL fractionator shall report the quantities of the constituents of the mixtures or blends separately. quantities of the constituents of the mixtures or blends separately.

NN 98.406(a)(1) (1) Annual quantity (in barrels) of each NGL product supplied to downstream facilities in the following product categories: ethane, propane, normal butane, isobutane, and pentanes plus. (1) Annual quantity (in barrels) of each NGL product supplied (including fractionated NGL products received from other
NGL fractionato rs) in the following product categories: ethane, propane, normal butane, isobutane, and pentanes plus (Fuelh in Equations NN

- 1 and NN

- 2). Clarifies equation term
to reduce confusion over which portion of NGL blends to report.

NN 98.406(a)(2) (2) Annual quantity (in barrels) of each NGL product received from other NGL fractionators in the following product categories: ethane, propane, normal butane, isobutane, and pentanes plus. (2) Annual quantity (in barrels) of each NGL product received
from other NGL fractionators in the following product categories: ethane, propane, normal butane, isobutane, and pentanes plus (Fuelg in Equation NN

- 7). Clarifies equation term
to reduce confusion over which portion of NGL blends to report.

NN 98.406(b)(1) (1) Annual vo lume in Mscf of natural gas received by the LDC at its city gate stations for redelivery on the LDC's distribution system, including for use by the LDC. (1) Annual volume in Mscf of natural gas received by the LDC at its city gate stations for redelivery o n the LDC's distribution system, including for use by the LDC (Fuelh in Equations NN

- 1 and NN

- 2). Clarifies equation term.

NN 98.406(b)(6) (6) Annual volume in Mscf of natural gas delivered to downstream gas transmission pipelines and other local distribution companies. (6) Annual volume in Mscf of natural gas delivered to downstream gas transmission pipelines and other local distribution companies (Fuel in Equation NN

- 3). Clarifies equation term.

NN 98.406(b)(12) (12) The customer name, address, and meter number of each large end

- user reported in paragraph (b)(7) of this section. Additionally, report whether the quantity of natural gas reported in paragraph (b)(7) of this section is the total quantity delivered to a large end

- user's facility, or

t he quantity delivered to a specific meter located at the facility. (i) If known, report the EIA identification number of each

LDC customer. (ii) [Reserved] (12) For each large end

- user reported in paragraph (b)(7) of this section, report: (i) The customer name, address, and meter number(s). (ii) Whether the quantity of natural gas reported in paragraph (b)(7) of this section is the total quantity delivered to a large end

- user's facility, or the quantity delivered to a specific meter located at the facility. (iii) If known, report the EIA identification number of each

LDC customer. Clarifies requirement.

NN 98.406(b)(13) (13) The annual volume in Mscf of natural gas delivered by the local distribution company to each of the following
end

- use categor ies. For definitions of these categories, refer to EIA Form 176 (Annual Report of Natural Gas and Supplemental Gas Supply & Disposition) and Instructions. (13) The annual volume in Mscf of natural gas delivered by the LDC (including natural gas that is not owned by the LDC) to each of the following end

- use categories. For definitions of these categories, refer to EIA Form 176 (Annual Report of Natural Gas and Supplemental Gas Supply & Disposition) and

Instructions. Clarifies reported data
element.

NN 98.406(b)(14) None (14) The name of the U.S. state or territory covered in this report submission. See preamble text for explanation.

NN Table NN

- 2 Table NN

- 2 See Appendix A for changes to Table NN

- 2. Editorial correction.

### 49 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

OO 98.410(a) (a) The industrial gas supplier source category consists of any facility that produces a fluorinated GHG or nitrous oxide, any bulk importer of fluorinated GHGs or nitrous oxide, and any bulk exporter of fluorinated GHGs or nitrous
oxide. (a) The industrial gas su pplier source category consists of any facility that produces fluorinated GHGs, fluorinated HTFs, or nitrous oxide; any bulk importer of fluorinated GHGs, fluorinated HTFs, or nitrous oxide; any bulk exporter of fluorinated GHGs, fluorinated HTFs, or nitro us oxide; and any facility that destroys fluorinated GHGs or fluorinated

HTFs. See preamble text for explanation.

OO 98.410(d) and (e) None (d) To produce a fluorinated HTF means to manufacture, from any raw material or feedstock chemical, a fluorinated GHG used for temperature control, device testing, cleaning substrate surfaces and other parts, and soldering in processes including but not limited to certain types of electronics manufacturing production processes. Fluorinated
heat transfer fluids do not include fluorinated GHGs used as
lubricants or surfactants. For fluorinated heat transfer fluids under this subpart OO, the lower vapor pressure limit of 1 mm Hg in absolute at 25 °C in the definition of fluorinated greenhouse gas in § 98.6 shall not apply . Fluorinated heat transfer fluids include, but are not limited to, perfluoropolyethers, perfluoroalkanes, perfluoroethers, tertiary perfluoroamines, and perfluorocyclic ethers. Producing a fluorinated HTF does not include the reuse or recycling of a fluor inated HTF, the creation of intermediates,
or the creation of fluorinated HTFs that are released or destroyed at the production facility before the production measurement at § 98.414(a).

(e) For purposes of this subpart OO, to destroy fluorinated

GHGs or fluorinated HTFs means to cause the expiration of a previously produced (as defined at § 98.410(b) and (d))
fluorinated GHG or fluorinated HTF to the destruction efficiency actually achieved. Such destruction does not result in a commercially useful end pr oduct. For purposes of this subpart OO, such destruction does not include HFC

- 23 destruction as defined at § 98.150 or the dissociation of fluorinated GHGs that occurs during electronics manufacturing as defined at § 98.90. For example, such
destruction do es not include the dissociation of fluorinated See preamble te xt for explanation.

### 50 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change GHGs that occurs during etch or chamber cleaning processes or during use of abatement systems that treat the fluorinated GHGs vented from such processes at electronics manufacturing facilities.

OO 98.412 You must report the GHG emissions that would result from
the release of the nitrous oxide and each fluorinated GHG that you produce, import, export, transform, or destroy during the calendar year. You must report the GHG emissions that would result from
the release of the nitrous oxide and each fluorinated GHG or fluorinated HTF that you produce, import, export, transform, or destroy during the calendar year. Harmonizing changes with proposed changes

to 98.410.

OO 98.413(a) (a) Calculate the total mass of each fluorinated GHG or nitrous oxide produced annually, except for amounts that are captured solely to be shipped off site for destruction, by using Equation OO

- 1 of this section:

P = Mass of fluorinated GHG or nitrous oxide produced annually.

P p = Mass of fluorinated GHG or nitrous oxide produced over the period “p”. (a) Calculate the total mass of each fluorinated GHG, fluorinated HTF, or nitrous oxide produced annually, except for amounts that are captured s olely to be shipped off site for destruction, by using Equation OO

- 1 of this section:

P = Mass of fluorinated GHG, fluorinated HTF, or nitrous oxide produced annually.

P p = Mass of fluorinated GHG, fluorinated HTF, or nitrous oxide produced over the pe riod “p”. Harmonizing changes with proposed changes

to 98.410.

OO 98.413(b) (b) Calculate the total mass of each fluorinated GHG or nitrous oxide produced over the period “p” by using Equation OO

- 2 of this section:

Where:

P p = Mass of fluorinated GHG or nitrous oxide produced over the period “p” (metric tons).

O p = Mass of fluorinated GHG or nitrous oxide that is measured coming out of the production process over the period p (metric tons).

U p = Mass of used fluorinated GHG o r nitrous oxide that is added to the production process upstream of the output measurement over the period “p” (metric tons). (b) Calculate the total mass of each fluorinated GHG, fluorinated HTF, or nitrous oxide produced over the period “p” by using Equ ation OO

- 2 of this section:

Where:

P p = Mass of fluorinated GHG, fluorinated HTF, or nitrous oxide produced over the period “p” (metric tons).

O p = Mass of fluorinated GHG, fluorinated HTF, or nitrous oxide that is measured coming out of the production process over the period p (metric tons).

U p = Mass of used fluorinated GHG, fluorinated HTF, or nitrous oxide that is added to the production proces s upstream of the output measurement over the period “p” (metric tons). Harmonizing changes with proposed changes

to 98.410.

OO 98.413(c) (c) Calculate the total mass of each fluorinated GHG or nitrous oxide transformed by using Equation OO

- 3 of this

se ction: (c) Calculate the total mass of each fluorinated GHG, fluorinated HTF, or nitrous oxide transformed by using Equation OO

- 3 of this section: Harmonizing changes with proposed changes

to 98.410.

### 51 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

Where:
T = Mass of fluorinated GHG or nitrous oxide transformed annually (metric tons).
FT = Mass of fluorinated GHG fed into the transformation process annually (metric tons).
ET = The fraction of the fluorinated GHG or nitrous oxide
fed into th e transformation process that is transformed in the process (metric tons). Where: T = Mass of fluorinated GHG, fluorinated HTF, or nitrous oxide transformed annually (metric tons).
FT = Mass of fluorinated GHG fed into the transformation process annually (metric tons). ET = The fraction of the fluorinated GHG, fluorinated HTF, or
nitrous oxide fed into the transfor mation process that is transformed in the process (metric tons).

OO 98.413(d) (d) Calculate the total mass of each fluorinated GHG destroyed by using Equation OO

- 4 of this section:

Where:

D = Mass of fluorinated GHG destroyed annually (metric tons).
FD = Mass of fluorinated GHG fed into the destruction device annually (metric tons). DE = Destruction efficiency of the destruction device (fraction). (d) Calculate the total mass of each fluorinated GHG or fluorinated HTF destroyed by using Equation OO

- 4 of this

section:

Where: D = Mass of fluorinated GHG or fluorinated HTF destroyed annually (metric tons).
FD = Mass of fluorinated GHG or fluorinated HTF fed into the destruction device annually (m etric tons). DE = Destruction efficiency of the destruction device (fraction). Harmonizing changes with proposed changes

to 98.410.

OO 98.414(a) (a) The mass of fluorinated GHGs or nitrous oxide coming out of the production process shall be measured using flowmeters, weigh scales, or a combination of volumetric and density measurements with an accuracy and precision of one percent of full scale or better. If the measured mass includes more than one fluorinated GHG, the
concentrations of each of the fl uorinated GHGs, other than
low

- concentration constituents, shall be measured as set forth in paragraph (n) of this section. For each fluorinated GHG, the mean of the concentrations of that fluorinated GHG (mass fraction) measured under paragraph (n) of thi s section shall be multiplied by the mass measurement to obtain the mass of that fluorinated GHG coming out of the production process. (a) The mass of fluorinated GHGs, fluorinated HTFs, or nitrous oxide coming out of the production process shall be

measur ed using flowmeters, weigh scales, or a combination of volumetric and density measurements with an accuracy and precision of one percent of full scale or better. If the
measured mass includes more than one fluorinated GHG or fluorinated HTF, the concentrat ions of each of the fluorinated GHGs or fluorinated HTFs, other than low

concentration constituents, shall be measured as set forth in paragraph (n) of this section. For each fluorinated GHG or fluorinated HTF, the mean of the concentrations of that
fluori nated GHG (mass fraction) measured under paragraph (n) of this section shall be multiplied by the mass
measurement to obtain the mass of that fluorinated GHG or fluorinated HTF coming out of the production process. Harmonizing changes with proposed changes

to 98.410.

### 52 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

OO 98.414(b) (b) The mass of any used fluorinated GHGs or used nitrous oxide added back into the production process upstream of the output measurement in paragraph (a) of this section shall be measured using flowmeters, weigh scales, or a
comb ination of volumetric and density measurements with an accuracy and precision of one percent of full scale or better. If the mass in paragraph (a) of this section is measured by weighing containers that include returned heels as well as newly produced fluo rinated GHGs, the
returned heels shall be considered used fluorinated GHGs for purposes of this paragraph (b) of this section and §98.413(b). (b) The mass of any used fluorinated GHGs, fluorinated HTFs, or used nitrous oxide added back into the production process upstream of the output measurement in paragraph (a) of this section shall be measured using flowmeters, weigh scales, or a combination of volumetric and density measurements with an accuracy and precision of one percent of full scale or better. If the mass in paragraph (a) of this section is measured by weighing containers that include returned heels as well as newly produced fluorinated GHGs or fluorinated HTFs, the returned heels shall be considered used fluorinated GHGs or fluorinated HTFs for pu rposes of this paragraph (b) of this section and § 98.413(b). Harmonizing changes with proposed changes

to 98.410.

OO 98.414(c) (c) The mass of fluorinated GHGs or nitrous oxide fed into the transformation process shall be measured using flowmeters, weigh scales, or a combination of volumetric and density measurements with an accuracy and precision of one percent of full scale or better. (c) The mass of fluorinated GHGs, fluorinated HTFs, or nitrous oxide fed into the transformation process shall be

m easured using flowmeters, weigh scales, or a combination of volumetric and density measurements with an accuracy and precision of one percent of full scale or better. Harmonizing changes with proposed changes

to 98.410.

OO 98.414(d) (d) The fraction of the fluorinated GHGs or nitrous oxide fed into the transformation process that is actually transformed shall be estimated considering yield calculations or quantities of unreacted fluorinated GHGs or nitrous oxide permanently removed from the process and

r ecovered, destroyed, or emitted. (d) The fraction of the fluorinated GHGs, fluorinated HTFs, or nitrous oxide fed into the transformation process that is actually transformed shall be estimated considering yield calculations or quantities of unreacted fluo rinated GHGs, fluorinated HTFs, or nitrous oxide permanently removed from the process and recovered, destroyed, or emitted. Harmonizing changes with proposed changes

to 98.410.

OO 98.414(e) (e) The mass of fluorinated GHG or nitrous oxide sent to
another facility for transformation shall be measured using flowmeters, weigh scales, or a combination of volumetric and density measurements with an accuracy and precision of one percent of full scale or better. (e) The mass of fluorinated GHGs, fluorinated HTFs , or nitrous oxide sent to another facility for transformation shall be measured using flowmeters, weigh scales, or a combination of volumetric and density measurements with an accuracy and precision of one percent of full scale or
better. Harmonizing chan ges with proposed changes

to 98.410.

OO 98.414(f) (f) The mass of fluorinated GHG sent to another facility for destruction shall be measured using flowmeters, weigh scales, or a combination of volumetric and density measurements with an accuracy and precision of one percent of full scale or better. If the measured mass
includes more than trace concentrations of materials other than the fluorinated GHG, the concentration of the fluorinated GHG shall be estimated considering current or previous representative concentration measurements and (f) The mass of fluorinated GHGs or fluorinated HTFs sent to
another facili ty for destruction shall be measured using flowmeters, weigh scales, or a combination of volumetric and density measurements with an accuracy and precision of one percent of full scale or better. If the measured mass
includes more than trace concentrations of materials other than the fluorinated GHG or fluorinated HTF, the
concentration of the fluorinated GHG or fluorinated HTF shall be estimated considering current or previous Harmonizing changes with proposed changes

to 98.410.

### 53 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change other relevant pro cess information. This concentration (mass fraction) shall be multiplied by the mass
measurement to obtain the mass of the fluorinated GHG sent to another facility for destruction. representative concentration measurements and other relevant process information . This concentration (mass fraction) shall be multiplied by the mass measurement to
obtain the mass of the fluorinated GHG or fluorinated HTF sent to another facility for destruction.

OO 98.414(g) (g) You must estimate the share of the mass of fluorinated GHGs in paragraph (f) of this section that is comprised of
fluorinated GHGs that are not included in the mass produced in §98.413(a) because they are removed from the production process as by

- products or other wastes. (g) You must estimate the share of the mass of fluorinated GHGs or fluorinated HTFs in paragraph (f) of this section that is comprised of fluorinated GHGs or fluorinated HTFs that are not included in the mass produced in § 98.413(a)
becaus e they are removed from the production process as by

- products or other wastes. Harmonizing changes with proposed changes

to 98.410.

OO 98.414(h) (h) You must measure the mass of each fluorinated GHG
that is fed into the destruction device and that was previously produced as defined at §98.410(b). Such fluorinated GHGs include but are not limited to quantities that are shipped to the facility by another facility for destruction and quantities that are returned to the facility
for reclamation but are foun d to be irretrievably contaminated and are therefore destroyed. You must use flowmeters, weigh scales, or a combination of volumetric and density measurements with an accuracy and precision of one percent of full scale or better. If the measured mass
inclu des more than trace concentrations of materials other than the fluorinated GHG being destroyed, you must estimate the concentrations of the fluorinated GHG being destroyed considering current or previous representative
concentration measurements and other relevant process information. You must multiply this concentration (mass fraction) by the mass measurement to obtain the mass of
the fluorinated GHG fed into the destruction device. (h) You must measure the mass of each fluorinated GHG or
fluorinated HTF t hat is fed into the destruction device and that was previously produced as defined at § 98.410(b). Such
fluorinated GHGs or fluorinated HTFs include but are not limited to quantities that are shipped to the facility by another facility for destruction and quantities that are returned to the facility for reclamation but are found to be irretrievably contaminated and are therefore destroyed. You must use flowmeters, weigh scales, or a combination of volumetric and density measurements with an accuracy and

pre cision of one percent of full scale or better. If the
measured mass includes more than trace concentrations of
materials other than the fluorinated GHG or fluorinated HTF being destroyed, you must estimate the concentrations of
the fluorinated GHG or fluor inated HTF being destroyed considering current or previous representative concentration measurements and other relevant process information. You must multiply this concentration (mass fraction) by the mass measurement to obtain the mass of
the fluorinated GHG or fluorinated HTF fed into the
destruction device. Harmonizing changes with proposed changes

to 98.410.

OO 98.414(i) (i) Very small quantities of fluorinated GHGs that are difficult to measure because they are entrained in other
media such as destroyed filters and destroyed sample containers are exempt from paragraphs (f) and (h) of this

section. (i) Very small quantities of fluorinated GHGs or fluorinated HTFs that are difficult to measure because they are
entrained in other media such as dest royed filters and destroyed sample containers are exempt from paragraphs (f) and (h) of this section. Harmonizing changes with proposed changes

to 98.410.

### 54 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

OO 98.414(l) (l) In their estimates of the mass of fluorinated GHGs destroyed, fluorinated GHG production facilities that destroy fluorinated GHGs shall account for any temporary reductions in the destruction efficiency that result from any startups, shutdowns, or malfunctions of the destruction device, including departures from the operating condit ions defined in state or local permitting requirements and/or oxidizer manufacturer specifications. (l) In their estimates of the mass of fluorinated GHGs or fluorinated HTFs destroyed, facilities that destroy
fluorinated GHGs or fluorinated HTFs shall acc ount for any temporary reductions in the destruction efficiency that result from any startups, shutdowns, or malfunctions of the destruction device, including departures from the operating conditions defined in state or local permitting requirements and/or oxidizer manufacturer specifications. Harmonizing changes with proposed changes

to 98.410.

OO 98.414(n) (n) If the mass coming out of the production process includes more than one fluorinated GHG, you shall
measure the concentrations of all of the fluorinated GHGs,
other than low

- concentration constituents, as follows: (n) If the mass coming out of the production process includes more than one fluorinated GHG or fluorinated HTF, you shall measure the concentrations of all of the
fluorinated GHGs or fluorinated HTFs, other than low

concentration constituents, as follows: Harmonizing changes with proposed changes

to 98.410.

OO 98.414(n)(3) (3) Frequency of measurement. Perform the measurements at least once by February 15, 2011 if the fluorinated GHG product is being produced on December 17, 2010. Perform the measurements within 60 days of commencing production of any fluorinated GHG product that was not being produced on December 17, 2010. Repeat the measurements if an operational or process change oc curs that could change the identities or significantly change the
concentrations of the fluorinated GHG constituents of the fluorinated GHG product. Complete the repeat measurements within 60 days of the operational or process change. (3) Frequency of meas urement. Perform the measurements at least once by February 15, 2011 if the fluorinated GHG product is being produced on December 17, 2010. Perform the measurements within 60 days of commencing production of any fluorinated GHG product that was not being p roduced on December 17, 2010. For fluorinated HTF products, perform the measurements at least once by February 15, 2017, if the fluorinated HTF product is being produced on January 1, 2017. Repeat the measurements if an operational or process change occurs that could change the identities or significantly change the concentrations of
the fluorinated GHG or fluorinated HTF constituents of the fluorinated GHG or fluorinated HTF product. Complete the repeat measurements within 60 days of the operational or

pro cess change. Harmonizing changes with proposed changes

to 98.410.

OO 98.414(n)(4) and (5) (4) Measure all product grades. Where a fluorinated GHG is produced at more than one purity level (e.g., pharmaceutical grade and refrigerant grade), perform the measurements for each purity level. (5) Number of samples. Analyze a minimum of three samples of the fluorinated GHG product that have been drawn under conditions that are representative of the process producing the fluorinated GHG product. If the
relative standard deviation of the measured concentrations of any of the fluorinated GHG constituents (other than low

- (4) Measure all product grades. Where a fluorinated GHG or fluorinated HTF is produced at more than one purity level (e.g., pharmaceutical grade and refrigerant grade), perform the measurements for each purity level

. (5) Number of samples. Analyze a minimum of three samples of the fluorinated GHGs or fluorinated HTF product that have been drawn under conditions that are representative of the process producing the fluorinated GHGs or fluorinated HTF product. If the re lative standard deviation of the measured concentrations of any of the fluorinated GHGs or Harmonizing changes with proposed changes

to 98.410.

### 55 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change concentration constituents) is greater than or equal to 15 percent, draw and analyze enough additional samples to
achieve a total of at least six samples of the fluorinated GHG product. fluorinated HTF constituents (other than low

- concentration constituents) is greater than or equal to 15 percent, draw and analyze enough additional samples to achiev e a total of at least six samples of the fluorinated GHG or fluorinated HTF product.

OO 98.414(o) (o) All analytical equipment used to determine the
concentration of fluorinated GHGs or fluorinated HTFs, including but ... (o) All analytical equipment used to determine the concentration of fluorinated GHGs or fluorinated HTFs, including but ... Harmonizing changes with proposed changes

to 98.410.

OO 98.416(a) (a) Each fluorinated GHG or nitrous oxide production facility shall report the following information: (1) Mass in metric tons of each fluorinated GHG or nitrous oxide produced at that facility by process, except for amounts that are captured solely to be shipped off site for
destruction. (2) Mass in metric tons of each fluorinated GHG or nitrous oxide transformed at that facility, by process. (3) Mass in metric tons of each fluorinated GHG that is destroyed at that facility and that was previously produced as defined at §98.410(b). Quantities to be reported under this paragraph (a)(3) of this section include but are not limited to quantities that are shipped to the facility by another facility for destruction and quantities that are returned to the facility for reclamation but are found to be

irretr ievably contaminated and are therefore destroyed.

.... (5) Total mass in metric tons of each fluorinated GHG or nitrous oxide sent to another facility for transformation. (6) Total mass in metric tons of each fluorinated GHG sent to another facility for de struction, except fluorinated GHGs that are not included in the mass produced in §98.413(a) because they are removed from the production process as by

- products or other wastes. Quantities to be reported under this paragraph (a)(6) could include, for exampl e, fluorinated GHGs that are returned to the facility for reclamation but are found to be irretrievably contaminated and are therefore sent to another facility for destruction. (a) Each fluor inated GHG, fluorinated HTF, or nitrous oxide production facility shall report the following information: (1) Mass in metric tons of each fluorinated GHG, fluorinated HTF, or nitrous oxide produced at that facility by process, except for amounts that are c aptured solely to be shipped
off site for destruction. (2) Mass in metric tons of each fluorinated GHG, fluorinated HTF, or nitrous oxide transformed at that facility, by process. (3) Mass in metric tons of each fluorinated GHG or
fluorinated HTF that is d estroyed at that facility and that was previously produced as defined at § 98.410(b). Quantities to be reported under this paragraph (a)(3) of this section include but are not limited to quantities that are shipped to the facility by another facility for d estruction and quantities that are returned to the facility for reclamation but are found to be irretrievably contaminated and are therefore destroyed.

.... (5) Total mass in metric tons of each fluorinated GHG, fluorinated HTF, or nitrous oxide sent to an other facility for
transformation. (6) Total mass in metric tons of each fluorinated GHG or fluorinated HTF sent to another facility for destruction, except fluorinated GHGs and fluorinated HTFs that are not included in the mass produced in § 98.413(a) bec ause they are removed from the production process as by

- products or other wastes. Quantities to be reported under this paragraph (a)(6) could include, for example, fluorinated GHGs that are returned to the facility for reclamation but Harmonizing changes with proposed changes

to 98.410.

### 56 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change (7) Total mass in metric tons of each fluorinated GHG that
is sent to another f acility for destruction and that is not included in the mass produced in §98.413(a) because it is removed from the production process as a byproduct or
other waste.

..... (10) Mass in metric tons of any fluorinated GHG or nitrous
oxide fed into the transfor mation process, by process. (11) Mass in metric tons of each fluorinated GHG that is fed into the destruction device and that was previously produced as defined at §98.410(b). Quantities to be reported under this paragraph (a)(11) of this section
include b ut are not limited to quantities that are shipped to the facility by another facility for destruction and quantities that are returned to the facility for reclamation but are found to be irretrievably contaminated and are therefore destroyed. (12) Mass in metric tons of each fluorinated GHG or nitrous oxide that is measured coming out of the production process, by process. (13) Mass in metric tons of each used fluorinated GHGs or nitrous oxide added back into the production process (e.g., for reclamation), including returned heels in containers that are weighed to measure the mass in §98.414(a), by

process. (14) Names and addresses of facilities to which any nitrous oxide or fluorinated GHGs were sent for transformation, and the quantities (metric tons) of n itrous oxide and of
each fluorinated GHG that were sent to each for
transformation. (15) Names and addresses of facilities to which any fluorinated GHGs were sent for destruction, and the quantities (metric tons) of each fluorinated GHG that were

sent to e ach for destruction. (16) Where missing data have been estimated pursuant to §98.415, the reason the data were missing, the length of time the data were missing, the method used to estimate the missing data, and the estimates of those data. are found to be irret rievably contaminated and are therefore sent to another facility for destruction. (7) Total mass in metric tons of each fluorinated GHG or fluorinated HTF that is sent to another facility for destruction and that is not included in the mass produced in § 9 8.413(a) because it is removed from the production process as a byproduct or other waste.

.... (10) Mass in metric tons of any fluorinated GHG, fluorinated HTF, or nitrous oxide fed into the transformation process, by

process. (11) Mass in metric tons of e ach fluorinated GHG or
fluorinated HTF that is fed into the destruction device and that was previously produced as defined at § 98.410(b). Quantities to be reported under this paragraph (a)(11) of this section include but are not limited to quantities that are shipped to the facility by another facility for destruction and quantities that are returned to the facility for reclamation but are found to be irretrievably contaminated and are therefore destroyed. (12) Mass in metric tons of each fluorinated GHG, fluorinated HTF, or nitrous oxide that is measured coming out of the production process, by process. (13) Mass in metric tons of each used fluorinated GHGs, fluorinated HTFs, or nitrous oxide added back into the production process (e.g., for reclamation), including returned heels in containers that are weighed to measure the mass in § 98.414(a), by process. (14) Names and addresses of facilities to which any nitrous oxide, fluorinated GHGs, or fluorinated HTFs were sent for transformation, and the quantitie s (metric tons) of nitrous
oxide and of each fluorinated GHG or fluorinated HTF that
were sent to each for transformation. (15) Names and addresses of facilities to which any
fluorinated GHGs or fluorinated HTFs were sent for destruction, and the quantitie s (metric tons) of each
fluorinated GHG or fluorinated HTF that were sent to each
for destruction.

### 57 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change (16) Where missing data have been estimated pursuant to § 98.415, the reason the data were missing, the length of time the data were missing, the method used to estimate the missing data, and the estimates of those data.

OO 98.416(b) (b) By March 31, 2011 or within 60 days of commencing fluorinated GHG destruction, whichever is later, a
fluorinated GHG production facility or importer that destroys fluorinated GHGs shall submit a one

- time report containing the following information for each destruction

process: (1) Destruction efficiency (DE). (2) Methods used to determine the destruction efficiency. (3) Methods used to record the mass of fluorinated GHG destroyed. (4) Chemical identity of the fluorinated GHG(s) used in the performance test conducted to determine DE. (5) Name of all applicable federal or state regulations that may apply to the destruction process. (6) If any process changes affect unit destruction efficiency
or the methods used to record mass of fluorinated GHG destroyed, then a revised report must be submitted to reflect the changes. The revised report must be submitted
to EPA within 60 da ys of the change. (b) By March 31, 2017 or within 60 days of commencing fluorinated GHG or fluorinated HTF destruction, whichever is later, any facility that destroys fluorinated GHGs or
fluorinated HTFs shall submit a one

- time report containing
the infor mation in paragraphs (b)(1) through (b)(6) of this section for each destruction process. Facilities that previously submitted a one

- time report under this paragraph are exempt from this requirement unless they meet the conditions in paragraph (b)(6) of thi s section. (1) Destruction efficiency (DE). (2) Methods used to determine the destruction efficiency. (3) Methods used to record the mass of fluorinated GHG or fluorinated HTF destroyed. (4) Chemical identity of the fluorinated GHG(s) used in the performance test conducted to determine DE. (5) Name of all applicable federal or state regulations that may apply to the destruction process. (6) If any process changes affect unit destruction efficiency
or the methods used to record mass of fluorinated G HG or fluorinated HTF destroyed, then a revised report must be submitted to reflect the changes. The revised report must be submitted to EPA within 60 days of the change. Harmonizing changes with proposed changes

to 98.410.

### 58 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

OO 98.416(c) (c) Each bulk im porter of fluorinated GHGs or nitrous oxide shall submit an annual report that summarizes its imports at the corporate level, except for shipments including less than twenty

- five kilograms of fluorinated GHGs or nitrous oxide, transshipments, and heels tha t meet the conditions set forth at §98.417(e). The report shall contain the following information for each import: (1) Total mass in metric tons of nitrous oxide and each fluorinated GHG imported in bulk, including each
fluorinated GHG constituent of the f luorinated GHG product that makes up between 0.5 percent and 100 percent of the product by mass. (2) Total mass in metric tons of nitrous oxide and each fluorinated GHG imported in bulk and sold or transferred to persons other than the importer for use in processes resulting in the transformation or destruction of the
chemical. (3) Date on which the fluorinated GHGs or nitrous oxide were imported. (4) Port of entry through which the fluorinated GHGs or nitrous oxide passed. (5) Country from which the imported fluorinated GHGs or nitrous oxide were imported. (6) Commodity code of the fluorinated GHGs or nitrous oxide shipped. (7) Importer number for the shipment. (8) Total mass in metric tons of each fluorinated GHG destroyed by the importer. (9) If app licable, the names and addresses of the persons
and facilities to which the nitrous oxide or fluorinated GHGs were sold or transferred for transformation, and the quantities (metric tons) of nitrous oxide and of each
fluorinated GHG that were sold or trans ferred to each facility for transformation. (10) If applicable, the names and addresses of the persons
and facilities to which the fluorinated GHGs were sold or transferred for destruction, and the quantities (metric tons) (c) Each bulk importer of fluorinated GHGs, fluorinated HTFs, or nitrous oxide shall submit an annual report that summarizes its imports at the corporate level, except for shipments including less than twenty

- five kilograms of fluorinated GHGs, fluorinated HTFs, or nitrous oxide, transshipments, and heels that meet the conditions set forth at § 98.417(e). The report shall contain the following information for each import: (1) Total mass in metric tons o f nitrous oxide and each fluorinated GHG or fluorinated HTF imported in bulk, including each fluorinated GHG or fluorinated HTF
constituent of the fluorinated GHG or fluorinated HTF product that makes up between 0.5 percent and 100 percent of the product b y mass. (2) Total mass in metric tons of nitrous oxide and each fluorinated GHG or fluorinated HTF imported in bulk and sold or transferred to persons other than the importer for use in processes resulting in the transformation or
destruction of the chemic al. (3) Date on which the fluorinated GHGs, fluorinated HTFs, or nitrous oxide were imported. (4) Port of entry through which the fluorinated GHGs, fluorinated HTFs, or nitrous oxide passed. (5) Country from which the imported fluorinated GHGs,
fluorinated HTFs, or nitrous oxide were imported. (6) Commodity code of the fluorinated GHGs, fluorinated HTFs, or nitrous oxide shipped. (7) Importer number for the shipment. (8) Total mass in metric tons of each fluorinated GHG or fluorinated HTF destroyed by the i mporter. (9) If applicable, the names and addresses of the persons and facilities to which the nitrous oxide, fluorinated GHGs,
or fluorinated HTFs were sold or transferred for transformation, and the quantities (metric tons) of nitrous
oxide and of each f luorinated GHG or fluorinated HTF that were sold or transferred to each facility for transformation. (10) If applicable, the names and addresses of the persons
and facilities to which the fluorinated GHGs or fluorinated Harmonizing changes with proposed changes

to 98.410.

### 59 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

of each fluorinated GHG that were sold or transferred to each facility for destruction. HTFs were sold or transferred for de struction, and the quantities (metric tons) of each fluorinated GHG or fluorinated HTF that were sold or transferred to each facility
for destruction.

OO 98.416(d) (d) Each bulk exporter of fluorinated GHGs or nitrous oxide shall submit an annual report that summarizes its exports at the corporate level, except for shipments including less than twenty

- five kilograms of fluorinated GHGs or nitrous oxide, transshipments, and heels. The report shall contai n the following information for each export: (1) Total mass in metric tons of nitrous oxide and each fluorinated GHG exported in bulk. (2) Names and addresses of the exporter and the recipient of the exports. (3) Exporter's Employee Identification Number. (4) Commodity code of the fluorinated GHGs and nitrous oxide shipped. (5) Date on which, and the port from which, fluorinated GHGs and nitrous oxide were exported from the United

States or its territories. (6) Country to which the fluorinated GHGs or nitro us oxide were exported. (d) Each bulk exporter of fluorinated GHGs, fluorinated HTFs, or nitrous oxide shall submit an annual report that summarizes its exports at the corporate level, except for shipments including less than twenty

- five kilograms of
fluo rinated GHGs, fluorinated HTFs, or nitrous oxide, transshipments, and heels. The report shall contain the following information for each export: (1) Total mass in metric tons of nitrous oxide and each fluorinated GHG or fluorinated HTF exported in bulk. (2 ) Names and addresses of the exporter and the recipient of the exports. (3) Exporter's Employee Identification Number. (4) Commodity code of the fluorinated GHGs, fluorinated HTFs, or nitrous oxide shipped. (5) Date on which, and the port from which, the fluorinated GHGs, fluorinated HTFs, or nitrous oxide were exported from
the United States or its territories. (6) Country to which the fluorinated GHGs, fluorinated HTFs, or nitrous oxide were exported. Harmonizing changes with proposed changes

to 98.410.

OO 98.416(i) & (j) None (i) Each facility that destroys fluorinated GHGs or fluorinated HTFs but does not otherwise report under this section shall report the mass in metric tons of each fluorinated GHG or fluorinated HTF that is destroyed at that facili ty and that was previously produced as defined at § 98.410(b) or (d), as applicable. Quantities to be reported under this paragraph (i) include but are not limited to quantities that are shipped to the facility by another facility for destruction and
quant ities that are returned to the facility for reclamation but are found to be irretrievably contaminated and are therefore destroyed. (j) By March 31, 2017, all fluorinated HTF production
facilities shall submit a one

- time report that includes the Harmonizing changes with proposed changes

to 98.410.

### 60 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change

concentrat ion of each fluorinated HTF or fluorinated GHG constituent in each fluorinated HTF product as measured under § 98.414(n). If the facility commences production of a fluorinated HTF product that was not included in the initial report or performs a repeat mea surement under § 98.414(n)
that shows that the identities or concentrations of the
fluorinated HTF or fluorinated GHG constituents of a fluorinated HTF product have changed, then the new or changed concentrations, as well as the date of the change,
must be provided in a revised report. The revised report must be submitted to EPA by the March 31st that immediately follows the new or repeat measurement under § 98.414(n).

OO 98.418 Low

- concentration constituent means, for purposes of fluorinated GHG production and export, a fluorinated GHG constituent of a fluorinated GHG product that occurs in the product in concentrations below 0.1 percent by mass. For purposes of fluorinated GHG import, low

- concent ration
constituent means a fluorinated GHG constituent of a fluorinated GHG product that occurs in the product in concentrations below 0.5 percent by mass. Low

concentration constituents do not include fluorinated GHGs that are deliberately combined with t he product (e.g., to affect the performance characteristics of the product). Low

- concentration constituent means, for purposes of fluorinated GHG or fluorinated HTF production and export, a
fluorinated GHG or fluorinated HTF constituent of a
fluorinated GH G or fluorinated HTF product that occurs in the product in concentrations below 0.1 percent by mass. For purposes of fluorinated GHG or fluorinated HTF import,
low

- concentration constituent means a fluorinated GHG or
fluorinated HTF constituent of a fluori nated GHG or fluorinated HTF product that occurs in the product in concentrations below 0.5 percent by mass. Low

concentration constituents do not include fluorinated GHGs or fluorinated HTFs that are deliberately combined with the product (e.g., to affect the performance characteristics of the product). Harmonizing changes with proposed changes

to 98.410.

PP 98.425(b) (b) Whenever the quality assurance procedures in §98.424(b) of this subpart cannot be followed to determine
concentration of the CO 2 stream, the most appropriate of the following missing data procedures shall be followed: (b) Whenever the quality assurance procedures in § 98.424(b) of this subpart cannot be followed to determine
concentration of the CO 2 stream, the most appropriate of the following missing data procedures shall be followed: Editorial correction.

RR 98.446(g) None (g) Whether the CO 2 stream is being injected into subsurface geologic formations to enhance the recovery of oil or natural

gas. See preamble text for explanation.

TT Table TT

- 1 See Table TT

- 1 See Appendix A for changes to Table TT

- 1 See preamble text for explanation.

TT Footnote "a"
to Table TT

- 1 a The applicable climate classification is determined based on the annual rainfall plus the recirculated leachate a The applicable climate classification is determined based on the annual rainfall plus the recirculated leachate application Editoria l correction; deletes duplicative text.

### 61 

### Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change application rate. Recirculated leachate application rate (in inches/year) is the total volume of leachate recirculated from company records or e ngineering estimates and applied to the landfill divided by the area of the portion of the landfill containing waste [with appropriate unit conversions]. (1) Dry climate = precipitation plus recirculated leachate less than 20 inches/year (2) Moderate c limate = precipitation plus recirculated leachate from 20 to 40 inches/year (inclusive) (3) Wet climate = precipitation plus recirculated leachate greater than 40 inches/year Alternatively, landfills that use leachate recirculation can
elect to use the k value for wet climate rather than calculating the recirculated leachate rate. (1)Dry climate = precipitation plus recirculated leachate less than 20 inches/year. (2)Moderate climate = precipitation plus recirculated leachate from 20 to 40 inches/yea r (inclusive). (3)Wet climate = precipitation plus recirculated leachate greater than 40 inches/year. rate. Recirculated leachat e application rate (in inches/year) is the total volume of leachate recirculated from company records or engineering estimates and applied to the landfill divided by the area of the portion of the landfill containing waste [with appropriate unit conversion s]. (1) Dry climate = precipitation plus recirculated leachate less than 20 inches/year (2) Moderate climate = precipitation plus recirculated leachate from 20 to 40 inches/year (inclusive) (3) Wet climate = precipitation plus recirculated leachate greater than 40 inches/year Alternatively, landfills that use leachate recirculation can
elect to use the k value for wet climate rather than calculating the recirculated leachate rate.

TT Footnote "b"
to Table TT

- 1 None b Kraft Recovery Wastes include green liquor dregs, slaker grits, and lime mud, which may also be referred to collectively as causticizing or recausticizing wastes. See preamble text for explanation.

UU 98.474(c)(2) (2) You must convert all measured volumes of CO 2 to the following standard industry temperature and pressure conditions for use in Equations UU

- 2 of this subpart: standard cubic meters at a temperature of 60 degrees Fahrenheit and at an absolute pressure of 1 atmosphere. (2) You must convert all measure d volumes of CO 2 to the following standard industry temperature and pressure conditions for use in Equation UU

- 2 of this subpart: standard cubic meters at a temperature of 60 degrees Fahrenheit and at an absolute pressure of 1 atmosphere. Editorial correct ion.

### 62 

# A ppendix A

1. Proposed Amendments to Table A

– 3 to Subpart A of Part 98

— Source Category List for § 98.2(a)(1)

Table A

- 3 to Subpart A of Part 98

— Source Category List for §98.2(a)(1)

Source Categories a 

### Applicable in Reporting Year 2010 and Future Years

Electricity generation units that report CO 2 

### mass emissions year round through 40 CFR part 75 (subpart D).

Adipic acid production (subpart E).

Aluminum production (subpart F).

Ammonia manufacturing (subpart G).

Cement production (subpart H).

HCFC

- 22 production (subpart O).

HFC

- 23 destruction processes that are not collocated with a HCFC

- 22 production facility and that destroy more than 2.14 metric tons of HFC

- 23 per year (subpart O).

Lime manufacturing (subpart S).

Nitric acid production (subpart V).

Petrochemical production (subpart X).

Petroleum refineries (subpart Y).

Phosphoric acid production (subpart Z).

Silicon carbide production (subpart BB).

Soda ash production (subpart CC).

Titanium dioxide production (subpart EE).

Municipal solid waste landfills that generate CH 4 

### in amounts equivalent to 25,000 metric tons CO 2 

### e or more per year, as determined according to subpart HH of this part.

Manure management systems with combined CH 4 

### and N 2 

### O emissions in amounts equival ent to 25,000 metric tons CO 2 

### e or more per year, as determined according to subpart JJ of this part.

Additional Source Categories a 

### Applicable in Reporting Year 2011 and Future Years

Electrical transmission and distribution equipment use at facilities where the total nameplate capacity of
SF 6 and PFC containing equipment exceeds 17,820 pounds, as determined under §98.301 (subpart DD).

Underground coal mines liberating 36,500,000 actual cubic feet of CH 4 

### or more per year (subpart FF).

Geologic sequestr ation of carbon dioxide (subpart RR).

Electrical transmission and distribution equipment manufacture or refurbishment (subpart SS).

Injection of carbon dioxide (subpart UU).

a 

### Source categories are defined in each applicable subpart. 

## 2. Proposed Amendments to Table A

– 4 to Subpart A of Part 98

— Source Category List for § 98.2(a)(2)

### 63 

## Table A

- 4 to Subpart A

— Source Category List for §98.2(a)(2)

Source Categories a 

### Applicable in Reporting Year 2010 and Future Years

Ferroalloy production (subpart K).

Glass production (subpart N).

Hydrogen production (subpart P).

Iron and steel production (subpart Q).

Lead production (subpart R).

Pulp and paper manufacturing (subpart AA).

Zinc production (subpart GG).

Additional Source Categories a 

### Applicable in Reporting Year 2011 and Future Years

Electronics manufacturing (subpart I)

Fluorinated gas production (subpart L)

Magnesium production (subpart T).

Petroleum and Natural Gas Systems (subpart W)

Industrial wastewater treatment (subpart II).

Industrial waste landfills (subpart TT).

a 

### Source categories are defined in each applicable subpart.



## 3. Proposed Amendments to Table A

– 5 to Subpart A of Part 98

— Supplier Category List for § 98.2(a)(4)

Table A

- 5 to Subpart A

— Supplier Category List f or §98.2(a)(4)

Supplier Categories a 

### Applicable in Reporting Year 2010 and Future Years

Coal

- to

- liquids suppliers (subpart LL):

(A) All producers of coal

- to

- liquid products.

(B) Importers of an annual quantity of coal

- to

- liquid products that is equivalent to 25,000 metric tons CO 2 

### e or more.
(C) Exporters of an annual quantity of coal

- to

- liquid products that is equivalent to 25,000 metric tons CO 2 

### e or more.
Petroleum product suppliers (subpart MM):

(A) All petroleum refineries that distill crude oil.

(B) Importers of an annual quantity of petroleum products and natural gas liquids that is equivalent to 25,000 metric tons CO 2 

### e or more.
(C) Exporters of an annual quantity of petroleum products and natural gas liquids that is equivalent to 25 ,000 metric tons CO 2 

### e or more.
Natural gas and natural gas liquids suppliers (subpart NN):

(A) All fractionators.

### 64 (B) Local natural gas distribution companies that deliver 460,000 thousand standard cubic feet or more of natural gas per year.

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 N 2 

### O, fluorinated GHG, fluorinated heat transfer fluids, and CO 2 

### that in combination are equivalent to 25,000 metric tons CO 2 

### e or more.
(C) Exporters of industrial greenhouse gases with annual bulk exports of N 2 

### O, fluorinated GHG, fluorinated heat transfer fluids, and CO 2 

### that in combination are equivalent to 25,000 metric tons CO 2 

### e or more.
(D) Fa cilities that destroy more than 25,000 mtCO2e or more of fluorinated GHGs or fluorinated heat transfer fluids annually

. Carbon dioxide suppliers (subpart PP):

(A) All producers of CO 2 

### . (B) Importers of CO 2 

### with annual bulk imports of N 2 

### O, fluorinated GHG, and CO 2 

### that in combination are equivalent to 25,000 metric tons CO 2 

### e or more.
(C) Exporters of CO 2 

### with annual bulk exports of N 2 

### O, fluorinated GHG, and CO 2 

### that in combination are equivalent to 25,000 metric tons CO 2 

### e or more.
Additional Supplier Categories Applicable a 

### in Reporting Year 2011 and Future Years

Importers and exporters of fluorinated greenhouse gases contained in pre

- charged equipment or closed

cell foams (subpart QQ):

(A) Importers of an annual quantity of fluorinated greenhouse gases contained in pre

charged equipment or closed

- cell foams that is equivalent to 25,000 metric tons CO 2 

### e or

more.
(B) Exporters of an annual quantity of fluorinated greenhouse gases contained in pre

charged equipment or closed

- cell foams that is equivalent to 25,000 metric tons CO 2 

### e or

more.

a 

### Suppliers are defined in each applicable subpart.



## 4. Proposed Amendments to Table C

– 1 to Subpart C of Part 98

— Default CO2 Emission Factors and High Heat Values for Various Types of Fuel

Table C

- 1 to Subpart C of Part 98

— Default CO 2 

## Emission Factors and High Heat Values for Various Types of Fuel

Default CO 2 

## Emission Factors and High Heat Values for Various Types o f Fuel

Fuel type Default high heat value Default CO 2 

### emission

factor

Coal and coke mmBtu/short ton kg CO 2 

### /mmBtu

### 65 Anthracite 25.09 103.69

Bituminous 24.93 93.28

Subbituminous 17.25 97.17

Lignite 14.21 97.72

Coal Coke 24.80 113.67

Mixed (Commercial sector) 21.39 94.27

Mixed (Industrial coking) 26.28 93.90

Mixed (Industrial sector) 22.35 94.67

Mixed (Electric Power sector) 19.73 95.52

Natural gas mmBtu/scf kg CO 2 

### /mmBtu

(Weighted U.S. Average) 1.026 × 10

− 3 

### 53.06

Petroleum products

— liquid mmBtu/gallon kg CO 2 

### /mmBtu

Distillate Fuel Oil No. 1 0.139 73.25

Distillate Fuel Oil No. 2 0.138 73.96

Distillate Fuel Oil No. 4 0.146 75.04

Residual Fuel Oil No. 5 0.140 72.93

Residual Fuel Oil No. 6 0.150 75.10

Used Oil 0.138 74.00

Kerosene 0.135 75.20

Liquefied petroleum gases (LPG) 1 

### 0.092 61.71

Propane 1 

### 0.091 62.87

Propylene 2 

### 0.091 67.77

Ethane 1 

### 0.068 59.60

### 66 Ethanol 0.084 68.44

Ethylene 2 

### 0.058 65.96

Isobutane 1 

### 0.099 64.94

Isobutylene 1 

### 0.103 68.86

Butane 1 

### 0.103 64.77

Butylene 1 

### 0.105 68.72

Naphtha (<401 deg F) 0.125 68.02

Natural Gasoline 0.110 66.88

Other Oil (>401 deg F) 0.139 76.22

Pentanes Plus 0.110 70.02

Petrochemical Feedstocks 0.125 71.02

Petroleum Coke 0.143 102.41

Special Naphtha 0.125 72.34

Unfinished Oils 0.139 74.54

Heavy Gas Oils 0.148 74.92

Lubricants 0.144 74.27

Motor Gasoline 0.125 70.22

Aviation Gasoline 0.120 69.25

Kerosene

- Type Jet Fuel 0.135 72.22

Asphalt and Road Oil 0.158 75.36

Crude Oil 0.138 74.54

Petroleum products

— solid mmBtu/short ton kg CO 2 

### /mmBtu

Petroleum Coke 30.00 102.41

### 67 Petroleum products

— gaseous mmBtu/scf kg CO 2 

### /mmBtu

Propane Gas 2.516 × 10

− 3 

### 61.46

Other fuels

— solid mmBtu/short ton kg CO 2 

### /mmBtu

Municipal Solid Waste 9.95 3 

### 90.7

Tires 28.00 85.97

Plastics 38.00 75.00

Petroleum Coke 30.00 102.41

Other fuels

— gaseous mmBtu/scf kg CO 2 

### /mmBtu

Blast Furnace Gas 0.092 × 10

− 3 

### 274.32

Coke Oven Gas 0.599 × 10

− 3 

### 46.85

Propane Gas 2.516 × 10

− 3 

### 61.46

Fuel Gas 4 

### 1.388 × 10

− 3 

### 59.00

Biomass fuels

— solid mmBtu/short ton kg CO 2 

### /mmBtu

Wood and Wood Residuals (dry basis) 5 

### 17.48 93.80

Agricultural Byproducts 8.25 118.17

Peat 8.00 111.84

Solid Byproducts 10.39 105.51

Biomass fuels

— gaseous mmBtu/scf kg CO 2 

### /mmBtu

Landfill Gas 0.485 × 10

− 3 

### 52.07

Other Biomass Gases 0.655 × 10

− 3 

### 52.07

Biomass Fuels

— Liquid mmBtu/gallon kg CO 2 

### /mmBtu

Ethanol 0.084 68.44

Biodiesel (100%) 0.128 73.84

### 68 Rendered Animal Fat 0.125 71.06

Vegetable Oil 0.120 81.55

1 

### The HHV for components of LPG determined at 60 °F and saturation pressure with the exception of ethylene.

2 

### Ethylene HHV determined at 41 °F (5 °C) and saturation pressure.

3 

### Use of this default HHV is allowed only for: (a) Units that combust MSW, do not generate steam, and are allowed to use Tier 1; (b) units that derive no more than 10 percent of the ir annual heat input from MSW and/or tires; and (c) small batch incinerators that combust no more than 1,000 tons of MSW per year.

4 

### Reporters subject to subpart X of this part that are complying with §98.243(d) or subpart Y of this part may only use the de fault HHV and the default CO 2 

### emission factor for fuel gas combustion under the conditions prescribed in §98.243(d)(2)(i) and (d)(2)(ii) and §98.252(a)(1) and (a)(2), respectively. Otherwise, reporters subject to subpart X or subpart Y shall use either Tie r 3 (Equation C

- 5) or Tier 4.

5 

### Use the following formula to calculate a wet basis HHV for use in Equation C

- 1: HHV w 

### = ((100 − M)/100)*HHV d 

### where HHV w 

### = wet basis HHV, M = moisture content (percent) and HHV d 

### = dry basis HHV from Table C

- 1.



## 5. Proposed Amendments to Table C

– 2 to Subpart C of Part 98

— Default CH4 and N2O Emission Factors for Various Types of Fuel

Table C

- 2 to Subpart C of Part 98

— Default CH 4 

## and N 2 

## O Emission Factors for Various Types of Fuel

Fuel type Default CH 4 

### emission factor (kg CH 4 

### /mmBtu) Default N 2 

### O emission factor (kg N 2 

### O/mmBtu)

Coal and Coke (All fuel types in Table C

- 1) 1.1 × 10

− 02 

### 1.6 × 10

− 03



### Natural Gas 1.0 × 10

− 03 

### 1.0 × 10

− 04



### Petroleum Products (All fuel types in Table C

- 1) 3.0 × 10

− 03 

### 6.0 × 10

− 04



### Fuel Gas 3.0 × 10

− 03 

### 6.0 × 10

− 04



### Municipal Solid Waste Other Fuels

— Solid 3.2 × 10

− 02 

### 4.2 × 10

− 03



### Tires 3.2 × 10

− 02 

### 4.2 × 10

− 03



### Blast Furnace Gas 2.2 × 10

− 05 

### 1.0 × 10

− 04



### Coke Oven Gas 4.8 × 10

− 04 

### 1.0 × 10

− 04



### Biomass Fuels

— Solid (All fuel types in Table C

- 1, except wood and wood residuals) 3.2 × 10

− 02 

### 4.2 × 10

− 03

### 69 Wood and wood residuals 7.2 × 10

− 03 

### 3.6 × 10

− 03



### Biomass Fuels

— Gaseous (All fuel types in Table C

- 1) 3.2 × 10

− 03 

### 6.3 × 10

− 04



### Biomass Fuels

— Liquid (All fuel types in Table C

- 1) 1.1 × 10

− 03 

### 1.1 × 10

− 04



### Note: Those employing this table are assumed to fall under the IPCC definitions of the “Energy Industry” or “Manufacturing Industries and Construction”. In all fuels except for coal the values for these two categories are identical. For coal combu stion, those who fall within the IPCC “Energy Industry” category may employ a value of 1g of CH 4 

### /mmBtu.



## 6. Proposed Amendments to Table I

- 3 to Subpart I of Part 98

— Default Emission Factors (1

– Uij) for Gas Utilization Rates (Uij) and By

- Product Formation R ates (Bijk) for Semiconductor Manufacturing for 150mm and 200 mm Wafer Sizes

Table I

– 3 to Subpart I of Part 98

— Default Emission Factors (1

– U ij 

## ) for Gas Utilization Rates (U ij 

## ) and By

- Product Formation Rates (B ijk 

## ) for Semiconductor Manufacturing for
150mm and 200 mm Wafer Sizes

Process type/Sub

type Process gas i

CF 4 

### C 2 

### F 6 

### CHF 3 

### CH 2 

### F 2 

### C 2 

### HF 5 

### CH 3 

### F C 3 

### F 8 

### C 4 

### F 8 

### NF 3 

### SF 6 

### C 4 

### F 6 

### C 5 

### F 8 

### C 4 

### F 8 

### O

ETCHING/WAFER CLEANING

1

–

U i 

### 0.81 0.72 0. 50 5 1 0.13 0.064 0. 51 70 NA 0.14 0.19 0.55 0.17 0.072 NA

BCF 4 

### NA 0.10 0.085 0.079 0.077 NA NA 0.11 0.0040 0.1 3 0.13 NA NA

BC 2 

### F 6 

### 0.046 NA 0.030 0.025 0.024 0.0034 

### NA NA 0.037 0.025 0.11 0.11 0.014 NA

BC 4 

### F 6 

### NA NA NA NA NA NA NA NA NA NA NA NA NA

BC 4 

### F 8 

### NA NA NA NA NA NA NA NA NA NA NA NA NA



### BC 3 

### F 8 

### NA NA NA NA NA NA NA NA NA NA NA NA NA

BC 5 

### F 8 

### 0.0012 NA 0.0012 NA NA NA NA 0.0086 NA NA NA NA NA

BCHF 3 

### 0.10 0.047 NA 0.049 NA NA
0.0034 NA 0.040 NA 0.0012 0.066 0.0039 NA



### CHAMBER CLEANING

In situ plasma cleaning:

### 70 

### Process type/Sub

type Process gas i

CF 4 

### C 2 

### F 6 

### CHF 3 

### CH 2 

### F 2 

### C 2 

### HF 5 

### CH 3 

### F C 3 

### F 8 

### C 4 

### F 8 

### NF 3 

### SF 6 

### C 4 

### F 6 

### C 5 

### F 8 

### C 4 

### F 8 

### O

1

–

U i 

### 0.92 0.55 NA NA NA NA 0.40 0.10 0.18 NA NA NA 0.14

BCF 4 

### NA 0.19 NA NA NA NA 0.20 0.11 0.050 NA NA NA 0.13

BC 2 

### F 6 

### NA NA NA NA NA NA NA NA NA NA NA NA 0.045

BC 3 

### F 8 

### NA NA NA NA NA NA NA NA NA NA NA NA NA

Remote plasma cleaning:

1

–

U i 

### NA NA NA NA NA NA NA NA 0. 018 01 7 NA NA NA NA

BCF 4 

### NA NA NA NA NA NA NA NA 0.015 NA NA NA NA

BC 2 

### F 6 

### NA NA NA NA NA NA NA NA NA NA NA NA NA

BC 3 

### F 8 

### NA NA NA NA NA NA NA NA NA NA NA NA NA

In situ thermal cleaning:

1

–

U i 

### NA NA NA NA NA NA NA NA NA NA NA NA NA

BCF 4 

### NA NA NA NA NA NA NA NA NA NA NA NA NA

BC 2 

### F 6 

### NA NA NA NA NA NA NA NA NA NA NA NA NA

BC 3 

### F 8 

### 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.



## 6 7 . Proposed Amendments to Table AA

– 2 to Subpart AA of Part 98

— Kraft Lime Kiln and
Calciner Emissions Factors for CH4 and N2O

Table AA

- 2 to Subpart AA of Part 98

— Kraft Lime Kiln and Calciner Emissions Factors for CH 4 

## and N 2 

## O

Fuel Fossil fuel

- based emissions factors (kg/mmBtu HHV)

Kraft rotary lime kilns Kraft calciners a

### 71 CH 4 

### N 2 

### O CH 4 

### N 2 

### O

Residual Oil (any type) 0.0027 0 0.0027 0.0003

Distillate Oil (any type) 0.0027 0 0.0027 0.0004

Natural Gas 0.0027 0 0.0027 0.0001

Biogas 0.0027 0 0.0027 0.0001

Petroleum coke 0.0027 0 b 

### NA b 

### NA

Other Fuels See Table C

- 2 0 See Table C

- 2 See Table C

- 2

a 

### Includes, for example, fluidized bed calciners at kraft mills.

a b 

### Emission factors for kraft calciners are not available.



## 7 8 . Proposed Amendments to Table HH

– 3 to Subpart HH of Part 98

— Landfill Gas
Collection Efficiencies

Table HH

- 3 to Subpart HH of Part 98

— Landfill Gas Collection Efficiencies

Description Landfill Gas Collection Efficiency

A1: Area with no waste in

- place Not applicable; do not use this area in the calculation.

A2: Area without active gas collection, regardless of cover type CE2: 0%.

A3: Area with daily soil cover and active gas collection CE3: 60%.

A4: Area with an intermediate soil cover, or a final soil cover not meeting the criteria for A5 below, and active gas collection CE4: 75%.

A5: Area with a final soil cover of 3 feet or thicker of clay or alternative final cover (as approved by the relevant agency) and/or geomembrane cover system and active gas c ollection CE5: 95%.

Weighted average collection efficiency for landfills:

Option 1: Area weighted average collection efficiency for landfills CEave1 = (A2*CE2 + A3*CE3 + A4*CE4 + A5*CE5) / (A2 + A3 + A4 + A5).

Option 2: Volume weighted average collection efficiency for landfills, where D2, D3, D4 and D5 are the waste depths for areas A2, A3, A4 and A5, respectively, as described above. CEave1 = (A2*D2*CE2 + A3*D3*CE3 + A4*D4*CE4 + A5*D5*CE5) / (A2*D2 + A3*D3 + A4*D4 + A5*D5).



## 8 9 . Proposed Amendments to Table HH

– 4 to Subpart HH of Part 98

— Landfill Methane
Oxidation Fractions

Table HH

- 4 to Subpart HH of Part 98

— Landfill Methane Oxidation Fractions

Under these conditions: Use this landfill
methane

### 72 oxidation
fraction:

I. For all reporting years prior to the 2013 reporting year

C1: For all landfills regardless of cover type or methane flux 0.10

II. For the 2013 reporting year and all subsequent years

C2: For landfills that have an alternative final cover (approved by the relevant agency) and/or a geomembrane (synthetic) cover with less than 12 inches of cover soil for greater than 50% the majority of the landfill area containing waste 0.0

C3: For landfills that do not meet the conditions in C2 above

, and for which you elect not to determine methane flux , and for landfills with passive vents/passive flares that service greater than 50% of the landfill area containing waste, or for landfills with only passive vents/passive flares or active venting 0.10

C4: For landfills that do not meet the conditions in C2 above and that do not have a soil cover of at least 24 inches intermediate or interim cover a 

### for greater than 50% a majority of the landfill area containing waste 0.10

C5: For landfills that have a soil cover of at least 24 inches intermediate or interim cover a 

### for greater than 50% a majority of the landfill area containing waste and for which the methane flux

rate b a 

### is less than 10 grams per square meter per day (g/m 2 

### /d) 0.35

C6: For landfills that have a soil cover of at least 24 inches intermediate or interim cover a 

### for greater than 50% a majority of the landfill area containing waste and for which the methane flux

rate b a 

### is 10 to 70 g/m 2 

### /d 0.25

C7: For landfills that have a soil cover of at least 24 inches intermediate or interim cover a 

### for a majority greater than 50% of the landfill area containing waste and for which the methane flux

rate b a 

### is greater than 70 g/m 2 

### /d 0.10

a 

### Where a landfill is located in a state that does not have an intermediate or interim cover requirement, the landfill must have soil cover of 12 inches or greater in order to use an oxidation fraction of 0.25 or 0.35.

b a 

### Methane flux rate (in grams per square meter per day; g/m 2 

### /d) is the mass flow rate of methane per unit area

at the bottom of the surface soil prior to any oxidation and is calculated as follows:

### 73 Where: MF = Methane flux rate from the landfill in the reporting year (grams per square meter per day, g/m 2 

### /d). K = unit conversion factor = 10 6 

### /365 (g/metric ton per da ys/year) or 10 6 

### /366 for a leap year. SArea = The surface area of the landfill containing waste at the beginning of the reporting year (square meters, m 2 

### ).
G CH4 

### = Modeled methane generation rate in reporting year from Equation HH

- 1 of this subpart or Equati on TT

- 1 of subpart TT of this part, as applicable, except for application with Equation HH

- 6 of this subpart (metric
tons CH 4 

### ). For application with Equation HH

- 6 of this subpart, the greater of the modeled methane generation rate in reporting year from Eq uation HH

- 1 of this subpart or Equation TT

- 1 of this part, as applicable, and the quantity of recovered CH 4 

### from Equation HH

- 4 of this subpart (metric tons CH 4 

### ). CE = Collection efficiency estimated at landfill, taking into account system coverage, operati on, and cover system materials from Table HH

- 3 of this subpart. If area by soil cover type information is not available, use default value of 0.75 (CE4 in table HH

- 3 of this subpart) for all areas under active influence of the collection system. N = Number of landfill gas measurement locations (associated with a destruction device or gas sent off

- site). If a single monitoring location is used to monitor volumetric flow and CH 4 

### concentration of the recovered gas sent to one or multiple destruction devices, then N=1.
R

n 

### = Quantity of recovered CH 4 

### from Equation HH

- 4 of this subpart for the nth measurement location (metric tons).
f Rec,n 

### = Fraction of hours the recovery system associated with the nth measurement location was operating (annual operating hours/8760 hours per year or annual operating hours/8784 hours per year for a leap year).



## 8 10 . Proposed Amendments to Table NN

– 2 to Subpar t NN of Part 98

— Default Values Factors for Calculation Methodology 2 of This Subpart

Table NN

- 2 to Subpart NN of Part 98

— Default Values Factors for Calculation Methodology 2 of This Subpart

Fuel Unit Default CO 2 

### emission value factor (MT CO 2 

### /Unit) 1



### Natural Gas Mscf 0.0544

Propane Barrel 0.241

Normal butane Barrel 0.281

Ethane Barrel 0.170

### 74 Isobutane Barrel 0.270

Pentanes plus Barrel 0.324

1 

### Conditions for emission value presented in MT CO 2 

### /bbl are 60 °F and saturation pressure.



## 9 11 . Proposed Amendments to Table TT

– 1 to Subpart TT of Part 98

— Default DOC and Decay Rate Values for Industrial Waste Landfills

Table TT

- 1 to Subpart TT of Part 98

— Default DOC and Decay Rate Values for Industrial Waste Landfills

Industry/Waste Type DOC (wei ght fraction, wet basis) k [dry
climate a 

### ] (yr

− 1 

### ) k [moderate
climate a 

### ] (yr

− 1 

### ) k [wet
climate a 

### ] (yr

− 1 

### )

Food Processing (other than industrial sludge) 0.22 0.06 0.12 0.18

Pulp and Paper Industry:

Boiler Ash 0.06 0.02 0.03 0.04

Wastewater Sludge 0.12 0.02 0.04 0.06

Pulp and Paper (other than industrial sludge ) 0. 20 0.02 0. 03 0. 04

Pulp and Paper Kraft Recovery
Wastes b 

### 0. 025 0.02 0.03 0.04

Other Pulp and Paper Wastes (not otherwise listed) 0.20 0.02 0.03 0.04

Wood and Wood Product (other than industrial sludge) 0.43 0.02 0.03 0.04

Construction and Demolition 0.08 0.02 0.03 0.04

Industrial Sludge (other than pulp and paper industry sludge) 0.09 0.02 0.04 0.06

Inert Waste [ i.e. , wastes listed in §98.460(c)(2)] 0 0 0 0

Other Industrial Solid Waste (not otherwise listed) 0.20 0.02 0.04 0.06

### 75 a 

### The applicable climate classification is determined based on the annual rainfall plus the recirculated leachate application rate. Recirculated leachate application rate (in inches/year) is the total volume of leachate recirculated from company records or engineering estimates and applied to the landfill divided by the area of the portion of the landfill containing waste [with appropriate unit conversions]. (1) Dry climate = precipitation plus recirculated leachate less than 20 inches/year (2) Moderate climate = precipitation plus recirculated leachate from 20 to 40 inches/year (inclusive) (3) Wet climate = precipitation plus recirculated leachate greater than 40 inches/year Alternatively, landfills that use leachate recirculation can elect to use the k value for wet climate rather than calculating the recirculated leachate rate.
(1) 

### Dry climate = precipitation plus recirculated leachate less than 20 inches/year.
(2) 

### Moderate climate = precipitation plus recirculated leachate from 20 to 40 inches/year (inclusive).

(3) 

### Wet climate = precipitation plus recirculated leachate greater than 40 inches/year.

b 

### Kraft Recovery Wastes include green liquor dregs, slaker grits, and lime mud, which may also be referred

to collectively as causticizing or recausticizing wastes.