1

MEMORANDUM

FROM: Rachel Schmeltz, Lisa Grogan-McCulloch, U.S. EPA, Climate Change Division

TO: Docket EPA-HQ-OAR-2015-0526 

DATE: December 11, 2015

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

1.0 INTRODUCTION

The 2009 final 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, 2009 

(74 FR 56260, October 30, 2009). The 2009 final 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 published in 2010 finalizing the 

requirements for subparts 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 these 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 accurately 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 action. 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 addressed 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 

several 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
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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 CORRECTIONS AND OTHER AMENDMENTS

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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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 A3 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 Table 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 the 

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 under §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 metric tons CO2e per year or more.

(2) If reported emissions are less than 15,000 metric tons 

CO2e per year for three consecutive years, then the owner 

or operator may discontinue complying with this part 

provided that the owner or operator submits a notification 

to the Administrator that announces the cessation of 

reporting and explains the reasons for the reduction in 

emissions. The notification shall be submitted no later than 

March 31 of the year immediately following the third 

consecutive year of emissions less than 15,000 tons CO2e 

per year. The owner or operator must maintain the 

corresponding records required under § 98.3(g) for each of 

the three consecutive years and retain such records for 

three years prior to notification of discontinuation of 

reporting following the year that reporting was 

discontinued. The owner or operator must resume reporting 

if annual emissions in any future calendar year increase to 

25,000 metric tons CO2e per year or more. 

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 supplier 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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section cease to operate, then the owner or operator is 

exempt from reporting in the 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 

and 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 which cessation of such operations occurs, 

provided that the owner or operator submits a notification 

to the Administrator that announces the cessation of 

reporting and certifies to the closure of all applicable 

processes and operations no later than March 31 of the year 

following such changes. If one or more processes or 

operations subject to paragraphs (a)(1) through (4) of this 

section at a facility or supplier cease to operate, but not all 

applicable processes or operations cease to operate, then 

the owner or operator is exempt from reporting for any such 

processes or operations in the reporting years following the 

reporting year in which cessation of the process or operation 

occurs, provided that the owner or operator submits a 

notification to the Administrator that announces the 

cessation of reporting for the process or operation no later 

than March 31 of the year following such changes. This 

paragraph (i)(3) does not apply to seasonal or other 

temporary cessation of operations. This paragraph (i)(3) 

does not apply to facilities with municipal solid waste 

landfills or industrial waste landfills, or to underground coal 

mines except those with abandoned status as determined by 

the U.S. Mine Safety & Health Administration. The owner or 

operator must resume reporting for any future calendar year 

during which any of the GHG-emitting processes or 

operations resume operation.

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 individually to each petroleum refinery, 

fractionator of natural gas liquids, local natural gas 

distribution company, and producer of CO2, N2O, or 

fluorinated greenhouse gases (e.g., a supplier of industrial 

greenhouse gases might qualify to discontinue reporting as 

an exporter of industrial greenhouse gases but still be 

See preamble text for 

explanation.
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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 supplier 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 operation no later than March 31 of the year 

following such changes. The owner or operator must resume 

complying with this part for the process or operation 

starting in any future calendar year during which the process 

or operation meets the "Definition of Source Category" as 

specified in an applicable subpart.

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.

Corrects 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 method of naming organic 

chemical compounds as recommended by the International 

Union of Pure and Applied Chemistry (IUPAC).

(2) The CAS registry number assigned by the Chemical 

Abstracts Registry Service. If a CAS registry number is not 

See preamble text for 

explanation.
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assigned or is not associated with a single fluorinated GHG 

or fluorinated heat transfer fluid, then report an 

identification number assigned by EPA’s Substance Registry 

Services. 

(3) Linear chemical formula.

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

category in Table A-5 to this subpart, 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 assigned by EPA’s 

Substance Registry Services.

(C) Linear chemical 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 missing data 

procedure was used for each parameter. Parameters include 

not only reported data elements, but any data element 

required for monitoring and calculating emissions.

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 

granted 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 30 days. The Administrator may grant an 

additional extension beyond the automatic 30-day extension 

See preamble text for 

explanation.
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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 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.

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 publication of the final rule in the Federal Register]

(i.e., for a facility or supplier that previously was not 

registered under this part). The list of subparts is not 

required for a revised COR.

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 destruction) or use. Landfill gas 

collection systems may also include knock-out or separator 

drums and/or a compressor. A single landfill may have 

multiple gas collection systems. Landfill gas collection 

systems do not include “passive” systems, whereby landfill

gas flows naturally 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 

locations in the landfill by means of a fan or similar 

mechanical draft equipment (forced convection) to a single 

location for treatment (thermal destruction) or use. Landfill 

gas collection systems may also include knock-out or 

separator drums and/or a compressor. A single landfill may 

have multiple gas collection systems. Landfill gas collection 

systems do not include “passive” systems, whereby landfill 

gas flows naturally (without forced convection) to the 

surface of the landfill where an opening or pipe (vent) is 

installed to allow for the flow of landfill gas to the 

atmosphere or to a remote flare installed to combust landfill 

gas that is passively emitted from the vent. Landfill gas 

collection systems also do not include “active venting” 

systems, whereby landfill gas is conveyed to the surface of 

the landfill using forced convection, but the landfill gas is 

See preamble text for 

explanation.
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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 exits employed at an 

underground coal mine to serve as the outlet or conduit to 

move air from the ventilation system out of the mine.

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 Radiocarbon 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 approved 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 mass 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 volume of the fuel combusted during the 

sample period “i,” (e.g., monthly, quarterly, semi-annually, 

or by lot) from company records (express mass in short tons 

See preamble text for 

explanation.
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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 liquid 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 CO2 mass emissions 

value by 1.1 to convert it to metric tons; 

(ii)(C) Divide the cumulative annual CO2 mass emissions 

value by 1.1 to convert it to metric tons; 

(iii)(C) Divide the cumulative annual CO2 mass emissions 

value by 1.1 to convert it to metric tons.

(i)(C) Divide the cumulative annual CO2 mass emissions value 

by 1.1023 to convert it to metric tons.; 

(ii)(C) Divide the cumulative annual CO2 mass emissions 

value by 1.1023 to convert it to metric tons.; 

(iii)(C) Divide the cumulative annual CO2 mass emissions 

value by 1.1023 to convert it to metric tons.

Corrects conversion 

factors 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 facility deems it necessary to obtain a 

representative sample. Notwithstanding this requirement, 

if the types of fuels combusted and their relative 

proportions are consistent throughout the year, the 

minimum required sampling time may be reduced to 8 

hours if at least two 8-hour samples and one 24-hour 

sample are collected under normal operating conditions, 

and arithmetic average of the biogenic fraction of the flue 

gas from the 8-hour samples (expressed as a decimal) is 

within ±5 percent of the biogenic fraction from the 24-hour 

test. There must be no overlapping of the 8-hour and 24-

(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 D6866-12 

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-

12 analysis at least once in every calendar quarter in which 

MSW is combusted in the unit. Collect each gas sample 

during normal unit operating conditions for at least 24 total 

(not necessarily consecutive) hours, or longer if the facility 

deems it necessary to obtain a representative sample. 

Notwithstanding this requirement, if the types of fuels 

combusted and their relative proportions are consistent 

throughout the year, the minimum required sampling time 

may be reduced to 8 hours if at least two 8-hour samples 

and one 24-hour sample are collected under normal 

operating conditions, and arithmetic average of the biogenic 

fraction of the flue gas from the 8-hour samples (expressed 

as a decimal) is within ±5 percent of the biogenic fraction 

from the 24-hour test. There must be no overlapping of the 

8-hour and 24-hour test periods. Document the results of 

See preamble text for 

explanation.
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hour test periods. Document the results of the 

demonstration in the unit's monitoring plan. If the types of 

fuels and their relative proportions are not consistent 

throughout the year, an optional sampling approach that 

facilities may wish to consider to obtain a more 

representative sample is to collect an integrated sample by 

extracting a small amount of flue gas (e.g., 1 to 5 cc) in each 

unit operating hour during the quarter. Separate the total 

annual CO2 emissions into the biogenic and non-biogenic 

fractions using the average proportion of biogenic 

emissions of all samples analyzed during the reporting year. 

Express the results as a decimal fraction (e.g., 0.30, if 30 

percent of the CO2 is biogenic). When MSW is the primary 

fuel for multiple units at the facility, and the units are fed 

from a common fuel source, testing at only one of the units 

is sufficient.

the demonstration in the unit's monitoring plan. If the types 

of fuels and their relative proportions are not consistent 

throughout the year, an optional sampling approach that 

facilities may wish to consider to obtain a more 

representative sample is to collect an integrated sample by 

extracting a small amount of flue gas (e.g., 1 to 5 cc) in each 

unit operating hour during the quarter. Separate the total 

annual CO2 emissions into the biogenic and non-biogenic 

fractions using the average proportion of biogenic emissions 

of all samples analyzed during the reporting year. Express 

the results as a decimal fraction (e.g., 0.30, if 30 percent of 

the CO2 is biogenic). When MSW is the primary fuel for 

multiple units at the facility, and the units are fed from a 

common fuel source, testing at only one of the units is 

sufficient.

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 which biomass and non-biogenic fuels are cofired 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 (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 

which biomass and non-biogenic fuels are co-fired in the 

unit. Follow the procedures in paragraph (d) of this section. 

If the primary fuel for multiple units at the facility consists of 

tires, and the units are fed from a common fuel source, 

testing at only one of the units is sufficient.

See preamble text for 

explanation.

C 98.36(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, excluding 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.
12

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 common 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 applicable) during the 

reporting year, in short tons for solid fuels, gallons for 

liquid fuels and standard cubic feet for gaseous fuels, or, if 

applicable, therms or mmBtu for natural gas.

(i) For the Tier 1 Calculation Methodology, report:

(A) The total quantity of each type of fuel combusted in the 

unit or group of aggregated units (as applicable) during the 

reporting year, in short tons for solid fuels, gallons for liquid 

fuels and standard cubic feet for gaseous fuels, or, if 

applicable, therms or mmBtu for natural gas.

(B) If applicable, the moisture content used to calculate the 

wood and wood residuals wet basis HHV for use in Equations 

C-1 and C-8, in percent. 

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 analysis, 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 (incorporated 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 analysis, 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 decimal 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 partlybiogenic fuels, including tires if you are electing to report 

biogenic CO2 emissions from tire combustion) and nonbiogenic fuels, you shall report the results of each quarterly 

sample analysis, expressed as a decimal fraction (e.g., if the 

biogenic fraction of the CO2 emissions is 30 percent, report 

0.30).

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 C1 and C-8).

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 

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 N2O 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 N2O 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 N2O emissions according to 

paragraphs (a)(2)(i) through (iv) of this section.

(i) If you received Administrator approval for an alternative 

method of determining N2O emissions in the previous 

reporting year and your methodology is unchanged, your 

alternative method is automatically approved for the next 

reporting year.

(ii) You must notify the EPA of your use of a previously 

approved alternative method in your annual report.

(iii) Otherwise, you must submit the request within 45 days 

following promulgation of this subpart or within the first 30 

days of each subsequent reporting year.

(iv) If the Administrator does not approve your requested

alternative method within 150 days of the end of the 

reporting year, you must determine the N2O emissions for 

the current reporting period using the procedures specified 

in paragraph (a)(1) of this section.

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, 

CO2 emissions can be estimated from aluminum production 

per Equation F-8 of this section. 

ECO2 = EFp x MPp + EFs x MPs (Eq. F-8)

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

CO2 emissions can be estimated from aluminum production 

by using Equation F-9 of this section.

ECO2 = EFp x MPp + EFs x MPs (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 

CF4/metric ton Al)/(mV/cell day)), potline overvoltage 

(mV/cell day), current efficiency (%).); 

(c)(3) Smelter-specific slope coefficients (or overvoltage 

emission factors) and the last date when the smelter-specific 

slope coefficients (or overvoltage emission factors) were 

measured.

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 

paragraphs (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 consumed.

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 byproduct 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 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 byproduct emissions of that gas calculated under this 

paragraph (a).

Corrects reference.

I 98.93, Eq. I-12 Nil = Number of containers of size and type l returned to 

the gas distributor containing the standard heel of input 

gas i.

Nil = Number of containers of size and type l used at the fab 

and returned to the gas distributor containing the standard 

heel of input gas i.

Clarifies that equation 

term is collected on a 

fab-basis.

I 98.93, Eq. I-12 Fil = Full capacity of containers of size and type l containing 

input gas i, on a fab basis (kg).

Fil = 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 I24A and I-24B of this subpart. ...

Harmonizing change 

with proposed edits to 

Equation I-24.
15

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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 quantifiable 

metric (e.g., the ratio of the number of tools that are 

expected to be vented to the stack system in the current 

year as compared to the previous reporting year, ratio of the 

expected number of wafer starts in the current reporting 

year as compared to the previous reporting year), 

engineering judgment, or other industry standard practice.

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 dif = Fraction of fluorinated GHG input gas i destroyed or 

removed in abatement systems connected to process tools 

in fab f, as calculated in Equation I-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.

dif = Fraction of fluorinated GHG input gas i destroyed or 

removed in abatement systems connected to process tools 

in fab f, as calculated in Equation I-24A of this subpart 

(expressed as decimal fraction). If the stack system does not 

have abatement systems on the tools vented to the stack 

system, the value of this parameter is zero.

Harmonizing change 

with proposed edits to 

Equation I-24.

I 98.93, Eq. I-20 dkf = Fraction of fluorinated GHG by-product gas k 

destroyed or removed in abatement systems connected to 

process tools in fab f, as calculated in Equation I-24 of this 

subpart (expressed as decimal fraction).

dkf = Fraction of fluorinated GHG by-product gas k destroyed 

or removed in abatement systems connected to process 

tools in fab f, as calculated in Equation I-24B of this subpart 

(expressed as decimal fraction).

Harmonizing change 

with proposed edits to 

Equation I-24.

I 98.93, Eq. I-21 dif = Fraction of fluorinated GHG input gas i destroyed or 

removed in abatement systems connected to process tools 

in fab f that are included in the stack testing option, as 

calculated in Equation I-24 of this subpart (expressed as 

decimal fraction).

dif = Fraction of fluorinated GHG input gas i destroyed or 

removed in abatement systems connected to process tools 

in fab f that are included in the stack testing option, as 

calculated in Equation I-24A of this subpart (expressed as 

decimal fraction).

Harmonizing change 

with proposed edits to 

Equation I-24.

I 98.93, Eq. I-22 dkf = Fraction of fluorinated GHG by-product k destroyed or 

removed in abatement systems connected to process tools 

in fab f that are included in the stack testing option, as 

calculated in Equation I-24 of this subpart (expressed as 

decimal fraction).

dkf = Fraction of fluorinated GHG by-product k destroyed or 

removed in abatement systems connected to process tools 

in fab f that are included in the stack testing option, as 

calculated in Equation I-24B of this subpart (expressed as 

decimal fraction).

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 this 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

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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. I24A

None (Eq. I-24-A) See preamble text for 

explanation.

I 98.93, Eq. I24B

None (Eq. I-24-B) See preamble text for 

explanation.

I 98.93, Eq. I24A and I-24BWhere:

dif=The average weighted fraction of fluorinated GHG input 

gas i destroyed or removed in abatement systems in fab f 

(expressed as a decimal fraction). 

Cijf=The amount of fluorinated GHG input gas i consumed 

for process type j fed into abatement systems in fab f as 

calculated using Equation I-13 of this subpart (kg). 

DREij=Destruction or removal efficiency for fluorinated GHG 

input gas i in abatement systems connected to process 

tools where process type j is used (expressed as a decimal 

fraction) determined according to § 98.94(f). 

f=fab. 

i=Fluorinated GHG input gas. j=Process type.

Where: 

dif = The average weighted fraction of fluorinated GHG input 

gas i destroyed or removed in abatement systems in fab f 

(expressed as a decimal fraction).

dkf = The average weighted fraction of fluorinated GHG 

byproduct gas k destroyed or removed in abatement 

systems in fab f (expressed as a decimal fraction).

Cijf = The amount of fluorinated GHG input gas i consumed 

for process type j fed into abatement systems in fab f as 

calculated using Equation I-13 of this subpart (kg).

(1 - Uij) = The default emission factor for input gas i used in 

process type j, from applicable Table I-3 to I-7 of this 

subpart.

Bijk = The default by-product gas formation rate factor for 

byproduct gas k from input gas i used in process type j, from 

applicable Table I-3 to I-7 of this subpart.

DREij = Destruction or removal efficiency for fluorinated GHG 

input gas i in abatement systems connected to process tools 

where process type j is used (expressed as a decimal 

fraction) determined according to § 98.94(f).

DREjk = 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 aij, the fraction of 

fluorinated GHG meeting the criteria in paragraph (i)(4)(i) 

of this section used in tools with abatement systems or that 

is used in tools with abatement systems that are vented to 

the stack systems that meet the criteria in paragraph 

(i)(4)(ii) of this section. You also must use the results of 

Equations I-24 of this subpart in place of the terms dij in 

Equation I-8 of this subpart and djk in Equation I-9 of this 

subpart and use the results of Equation I-23 of this subpart 

in place of the results of Equation I-15 of this subpart for 

the term UTij.

(4) ... You must use, in place of the term aij, the fraction of 

fluorinated GHG meeting the criteria in paragraph (i)(4)(i) of 

this section used in tools with abatement systems or that is 

used in tools with abatement systems that are vented to the 

stack systems that meet the criteria in paragraph (i)(4)(ii) of 

this section. You also must use the results of Equations I-24A 

and I-24B of this subpart in place of the terms dij in Equation 

I-8 of this subpart and djk in Equation I-9 of this subpart,

respectively, and use the results of Equation I-23 of this 

subpart in place of the results of Equation I-15 of this 

subpart for the term UTij.

Harmonizing change 

with proposed edits to 

Equation I-24.

I 98.94(f) (f) If your fab employs abatement systems and you elect to 

reflect emission reductions due to these systems, or if your 

fab employs abatement systems designed for fluorinated 

GHG abatement and you elect to calculate fluorinated GHG 

emissions using the stack test method under 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.

(f) If your fab employs abatement systems and you elect to 

reflect emission reductions due to these systems, or if your 

fab employs abatement systems designed for fluorinated 

GHG abatement and you elect to calculate fluorinated GHG 

emissions using the stack test method under § 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 paragraphs (j)(5)(ii)(A) and 

(B) of this section are met, you may use the arithmetic 

average of the three emission factors for each fluorinated 

GHG and fluorinated GHG by-product for the current year 

and the next 4 years with no further testing unless your fab 

operations are changed in a way that triggers the re-test 

criteria in paragraph (j)(8) of this section. ...

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

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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 calculation 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 element.

I 98.96(r)(2) (2) ... dif = 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) ... dif = Fraction of fluorinated GHG i destroyed or 

removed in abatement systems connected to process tools 

in fab f, as calculated from Equation I-24A, 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) ... dkf = 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) ... dkf = Fraction of fluorinated GHG by-product k 

destroyed or removed in abatement systems connected to 

process tools in fab f, as calculated from Equation I-24B, 

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 and by-product formation 

rates and/or destruction or removal efficiency data that 

have been collected in the previous 3 years that support the 

changes in semiconductor manufacturing processes 

described in the report. For any utilization, by-product 

formation rate, and/or destruction or removal efficiency 

data submitted, the report must describe, where available: 

methods used for the measurements, wafer size, film type 

being manufactured, substrate type, the linewidth or 

technology node, process type, process subtype for chamber 

clean processes, the input gases used and measured, the 

utilization rates measured, and the by-product formation 

rates measured.

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 include 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 site-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 sampling 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 on an annual basis the calcination fraction for 

each carbonate consumed based on sampling and chemical 

analysis using an industry consensus standard. If performed, 

this chemical analysis must be conducted using an x-ray 

fluorescence test or other enhanced testing method 

published by an industry consensus standards organization 

(e.g., ASTM, ASME, API, etc.).

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 carbonatebased 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 included in calculating process 

emissions in Equation N-1 of this subpart, if applicable.

See preamble text for 

explanation.
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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 carbonatebased 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 destruction 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

CO2 = Annual CO2 emissions from fuel and feedstock 

consumption in metric tons per month (metric tons/yr).

CO2 = Annual CO2 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 measurements (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 gaseous 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) according 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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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 CO2 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 

“CR”).

Q Equation Q10Corrects equation term 

(updates “lux” to “Flux”).

Q Equation Q11Corrects equation 

(removes “+ I”).

Q Equation Q12Corrects equation term 

(updates “Cg,f,I” to 

“Cgf,i”).

Q Equation Q12n = 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 CO2 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 CO2 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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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 N2O 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 N2O emissions for 

the current reporting period using the procedures specified 

in paragraph (a)(1) of this section.

(2) Request Administrator approval for an alternative 

method of determining N2O 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 N2O emissions in the previous 

reporting year and your methodology is unchanged, your 

alternative method is automatically approved for the next 

reporting year.

(ii) You must notify the EPA of your use of a previously 

approved alternative method in your annual report.

(iii) Otherwise, you must submit the request within 45 days 

following promulgation of this subpart or within the first 30 

days of each subsequent reporting year.

(iv) If the Administrator does not approve your requested 

alternative method within 150 days of the end of the 

reporting year, you must determine the N2O emissions for 

the current reporting period using the procedures specified 

in paragraph (a)(1) of this section.

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 onsite production of other 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 petrochemical production source category includes 

processes that produce the petrochemical as an 

intermediate in the on-site production of other chemicals as 

well as processes that produce the petrochemical as an end 

product for sale or shipment off site.

See preamble text for 

explanation.
23

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

(3) When ethylene dichloride and vinyl chloride monomer 

are produced in an integrated process, you may consider the 

entire integrated process to be the petrochemical process 

for the purpose of complying with the mass balance option 

in § 98.243(c). If you elect to consider the integrated 

process to be the petrochemical process, then the mass 

balance must be performed over the entire integrated 

process.

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

once per 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 liquid or solid 

feedstock is delivered in lots, and if multiple deliveries of 

the same feedstock are received from the same supply 

source in a given calendar month, only one representative 

sample is required. Alternatively, you may use the results 

of analyses conducted by a feedstock supplier, or product 

customer, provided the sampling and analysis is conducted 

at least once per month using any of the procedures 

specified in §98.244(b)(4).

(3) Collect a sample of each feedstock and product at least 

once per month and determine the molecular weight (for 

gaseous materials when the quantity is measured in scf) and 

carbon content of each sample according to the procedures 

of § 98.244(b)(4). If multiple valid molecular weight or 

carbon content measurements are made during the monthly 

measurement period, average them arithmetically. 

However, if a particular liquid or solid feedstock is delivered 

in lots, and if multiple deliveries of the same feedstock are 

received from the same supply source in a given calendar 

month, only one representative sample is required. 

Alternatively, you may use the results of analyses conducted 

by a feedstock supplier, or product customer, provided the 

sampling and analysis is conducted at least once per month 

using any of the procedures specified in § 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.
24

Table of 2015 Revisions to the Greenhouse Gas Reporting Rule

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

ethylene dichloride production (metric tons) or both the 

measured quantity of vinyl chloride monomer production 

(metric tons) and an estimate of the ethylene dichloride 

production (metric tons).

X 98.246(a)(6) (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 device (e.g., flow meter, 

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) through (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 to 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 product.

(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 offgas 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 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), 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).

Clarifies reporting 

requirements.
25

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 petrochemical 

process is an integrated ethylene dichloride and vinyl 

chloride monomer process, report either the measured 

ethylene dichloride production (metric tons) or both the 

measured quantity of vinyl chloride monomer production 

(metric tons) and an estimate of the ethylene dichloride 

product (metric tons).

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 offgas 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 emissions 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.

Clarifies 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 

requirements 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 asphalt 

blowing operations controlled either by vapor scrubbing or 

See preamble text for 

explanation.
26

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

CO2 and CH4 emissions using Equations Y-14 and Y-15 of 

this section, respectively.

by another non-combustion control device, calculate CO2

and CH4 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 CO2 using either Equation Y-16a 

or Equation Y-16b of this section and calculate CH4 

emissions using Equation Y-17 of this section, provided 

these emissions are not already included in the flare 

emissions calculated in paragraph (b) of this section or in 

the stationary combustion unit emissions required under 

subpart C of this part (General Stationary Fuel Combustion 

Sources).

(2) For asphalt blowing operations controlled by either a 

thermal oxidizer, a flare, or other vapor combustion control 

device, calculate CO2 using either Equation Y-16a or 

Equation Y-16b of this section and calculate CH4 emissions 

using Equation Y-17 of this section, provided these emissions 

are not already included in the flare emissions calculated in 

paragraph (b) of this section or in the stationary combustion 

unit emissions required under subpart C of this part (General 

Stationary Fuel Combustion Sources).

See preamble text for 

explanation.

Y 98.253(h)(2); 

Equation Y16a

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 Y16b

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 coking 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 it 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 CH4 emissions from the 

depressurization of the coke drum or vessel regardless of 

the CH4 concentration and also calculate the CH4 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 CH4 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 produced 

by the delayed coking unit. Alternatively, you may estimate 

the typical dry mass of coke produced per cycle based on the 

delayed coking unit vessel (coke drum) dimensions and 

typical coke drum outage at the end of the coking cycle 

using Equation Y-18a of this section. 

( ) 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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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 CH4 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 the 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, 

gauge 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 prior 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 (kgmole CH4/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 the 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/ft3). Use the default value of 0.0191 mt/ft3

Hdrum = Internal height of delayed coking unit vessel (feet).

Houtage= Typical distance from the top of the delayed 

coking unit vessel to the top of the coke bed (i.e., coke drum 

outage) at the end of the coking cycle (feet) from company 

records or engineering estimates.

D = Diameter of delayed coking unit vessel (feet).

(2) Determine the typical mass of water in the delayed 

coking unit vessel at the end of the cooling cycle prior to 

venting to the atmosphere using Equation Y-18b of this 

section. 

( ) 2

coke

water water water

particle

π D M

M ρ H 4 ρ

  ×

=× × −    

(Eq. Y-18b)

Where:

Mwater= Mass of water in the delayed coking unit vessel at 

the end of the cooling cycle just prior to atmospheric venting 

(metric tons/cycle).

ρwater = Density of water at average temperature of the 

delayed coking unit vessel at the end of the cooling cycle just 

prior to atmospheric venting (metric tons per cubic feet; 

mt/ft3). Use the default value of 0.0270 mt/ft3.

Hwater= Typical distance from the bottom of the coking unit 

vessel to the top of the water level at the end of the cooling 

cycle just prior to atmospheric venting (feet) from company 

records or engineering estimates.

Mcoke = Typical dry mass of coke in the delayed coking unit 

vessel at the end of the coking cycle (metric tons/cycle) as 

determined in paragraph (i)(1) of this section.

ρparticle = Particle density of coke (metric tons per cubic 

feet; mt/ft3). Use the default value of 0.0382 mt/ft3

D = Diameter of delayed coking unit vessel (feet).
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Subpart Citation(s) Current Rule Text Proposed Rule Text Rationale for Change 

or vessels to calculate the CH4 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.

Where:

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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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-18e)

Where:

Msteam = Mass of steam generated and released per 

decoking cycle (metric tons/cycle).

fConvLoss = fraction of total heat loss that is due to 

convective heat loss from the sides of the coke vessel 

(unitless). Use the default value of 0.10.

Mwater= Mass of water in the delayed coking unit vessel at 

the end of the cooling cycle just prior to atmospheric venting 

(metric tons/cycle).

Cp,water = Heat capacity of water (British thermal units per 

metric ton per degree Fahrenheit; Btu/mt-°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 delayed 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 CH4 emissions from decoking operations at 

each delayed coking unit using Equation Y-18f of this section.

Where:

CH4 = Annual methane emissions from the delayed coking 

unit’ decoking operations (metric ton/year).
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Msteam = Mass of steam generated and released per 

decoking cycle (metric tons/cycle) as determined in 

paragraph (i)(3) of this section.

EmFDCU = Methane emission factor for delayed coking unit 

(kilograms CH4 per metric ton of steam; kg CH4/mt steam) 

from unit-specific measurement data. If you do not have 

unit-specific measurement data, use the default value of 7.9 

kg CH4/metric ton steam.N = Cumulative number of 

decoking cycles (or coke-cutting cycles) for all delayed coking 

unit vessels associated with the delayed coking unit during 

the year.

0.001 = Conversion factor (metric ton/kg).

Y 98.253(j) (j) For each process vent not covered in paragraphs (a) 

through (i) of this section that can reasonably be expected 

to contain greater than 2 percent by volume CO2 or greater 

than 0.5 percent by volume of CH4 or greater than 0.01 

percent by volume (100 parts per million) of N2O, calculate 

GHG emissions using Equation Y-19 of this section. You 

must also use Equation Y-19 of this section to calculate CH4

emissions for catalytic reforming unit depressurization and 

purge vents when methane is used as the purge gas, CH4

emissions if you elected to use the method in paragraph 

(i)(1) of this section, and CO2 and/or CH4 emissions, as 

applicable, if you elected this method as an alternative to 

the methods in paragraphs (f), (h), or (k) of this section.

(j) For each process vent not covered in paragraphs (a) 

through (i) of this section that can reasonably be expected to 

contain greater than 2 percent by volume CO2 or greater 

than 0.5 percent by volume of CH4 or greater than 0.01 

percent by volume (100 parts per million) of N2O, calculate 

GHG emissions using Equation Y-19 of this section. You must 

also use Equation Y-19 of this section to calculate CH4

emissions for catalytic reforming unit depressurization and 

purge vents when methane is used as the purge gas, and CO2

and/or CH4 emissions, as applicable, if you elected this 

method as an alternative to the methods in paragraphs (f), 

(h), or (k) of this section.

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 

accuracy of measurements made with these devices shall 

(j) Determine the quantity of petroleum process streams 

using company records. These quantities include the 

quantity of coke produced per cycle, asphalt blown, quantity 

of crude oil plus the quantity of intermediate products 

received from off site, and the quantity of unstabilized crude 

oil received at the facility.

(k) Determine temperature or pressure of delayed coking 

unit vessel using process instrumentation operated, 

maintained, and calibrated according to the manufacturer's 

instructions.

(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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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 estimates 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 flare, 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 average 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 CH4 emissions (in metric tons of 

CH4) for all delayed coking units at the facility.

(2) A description of the method used to calculate the CH4

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/kgmole 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 unit, in bbl/stream 

day.

(3) Annual quantity of coke produced in the unit during the 

reporting year, in metric tons.

(4) The calculated annual CH4 emissions (in metric tons of 

CH4) for the delayed coking unit.

(5) The total number of delayed coking vessels (or coke 

drums) associated with the delayed coking unit.

(6) The basis for the typical dry mass of coke in the delayed 

coking unit vessel at the end of the coking cycle (mass 

measurements from company records or calculated using 

Equation Y-18a).

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

(6) If you use Equation Y-19 of this subpart, the relevant 

information 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 default 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 

in §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 data 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 provided 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) Volumetric 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 

company 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 coking 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 

delayed 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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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 CH4 per metric ton of steam; kg CH4/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 (Equation 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 each 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 correction.

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 CO2 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 

CO2 emissions if the respective monitoring and QA/QC 

requirements described in §98.34 are met.

(1) Calculate fossil fuel-based CO2 emissions from direct 

measurement of fossil fuels consumed and default emissions 

factors according to the Tier 1 methodology for stationary 

combustion sources in § 98.33(a)(1). Tiers 2 or 3 from § 

98.33(a)(2) or (3) may be used to calculate fossil fuel-based 

CO2 emissions if the respective monitoring and QA/QC 

requirements described in § 98.34 are met.

See preamble text for 

explanation.

AA 98.273(b)(1) (1) Calculate fossil CO2 emissions from fossil fuels from 

direct measurement of fossil fuels consumed and default 

emissions factors according to the Tier 1 Calculation 

Methodology for stationary combustion sources in 

§98.33(a)(1). A higher tier from §98.33(a) may be used to 

calculate fossil fuel-based CO2 emissions if the respective 

monitoring and QA/QC requirements described in §98.34 

are met.

(1) Calculate fossil CO2 emissions from fossil fuels from 

direct measurement of fossil fuels consumed and default 

emissions factors according to the Tier 1 Calculation 

Methodology for stationary combustion sources in § 

98.33(a)(1). Tiers 2 or 3 from § 98.33(a)(2) or (3) may be 

used to calculate fossil fuel-based CO2 emissions if the 

respective monitoring and QA/QC requirements described in 

§ 98.34 are met.

See preamble text for 

explanation.
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AA 98.273(c)(1) (1) Calculate CO2 emissions from fossil fuel from direct 

measurement of fossil fuels consumed and default HHV 

and default emissions factors, according to the Tier 1 

Calculation Methodology for stationary combustion 

sources in §98.33(a)(1). A higher tier from §98.33(a) may 

be used to calculate fossil fuel-based CO2 emissions if the 

respective monitoring and QA/QC requirements described 

in §98.34 are met.

(1) Calculate CO2 emissions from fossil fuel from direct 

measurement of fossil fuels consumed and default HHV and 

default emissions factors, according to the Tier 1 Calculation 

Methodology for stationary combustion sources in § 

98.33(a)(1). Tiers 2 or 3 from § 98.33(a)(2) or (3) may be 

used to calculate fossil fuel-based CO2 emissions if the 

respective monitoring and QA/QC requirements described in 

§ 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.

Editorial 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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(1) New hermetically sealed-pressure switchgear during the 

year. 

(2) New SF6- or PFC-insulated equipment other than 

hermetically sealed-pressure switchgear during the year.

(3) Retired hermetically sealed-pressure switchgear during 

the year. 

(4) Retired SF6- or PFC-insulated equipment other than 

hermetically sealed-pressure switchgear during the year.

FF 98.323(a) (a) For each ventilation shaft, vent hole, or centralized 

point into which CH4 from multiple shafts and/or vent holes 

are collected, you must calculate the quarterly CH4

liberated from the ventilation system using Equation FF-1 

of this section. You must measure CH4 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 CH4).

V = Volumetric flow rate for the quarter (acfm) based on 

sampling or a flow rate meter. If a flow 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 measured 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 CH4 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 point 

into which CH4 from multiple shafts and/or vent holes are 

collected, you must calculate the quarterly CH4 liberated 

from the ventilation system using Equation FF-1 of this 

section. You must measure CH4 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 CH4).

V = Volumetric flow rate for the quarter (acfm) based on 

sampling or a flow rate meter. If a flow 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 measured 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 CH4 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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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 CH4 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 CH4 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).

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 

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.

(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 measurements. 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 text for 

explanation.

FF 98.323(b); 

Equation FF-3

CH4D = Weekly CH4 liberated from at the monitoring point 

(metric tons CH4). 

CH4D = Weekly CH4 liberated from the monitoring point 

(metric tons CH4).

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 total 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.
37

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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 CH4 liberated from degasification 

systems for the mine should be determined as the sum of 

CH4 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 CH4

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 and 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 

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, 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 or 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 sampling 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-V1, February 2013 (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 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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station may be used as a default for pressure. If the MSHA 

data for methane flow is provided in 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 CH4 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 CH4

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 CH4 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 (quarterly 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 flow 

meter automatically corrects for moisture content.

(g) Quarterly CH4 concentration for each ventilation 

monitoring point, dates and locations of each measurement, 

and method of measurement (sampling or continuous 

monitoring). Specify whether the CH4 concentration 

measurement at each ventilation monitoring point is on dry 

basis or wet basis.

(h) Weekly volumetric flow rate used to calculate CH4

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 automatically corrects for 

moisture content.

See preamble text for 

explanation.
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(i) Quarterly CH4 concentration (%) used to calculate CH4

liberated from degasification systems, and if the data is 

based on CEMS or weekly sampling. Specify whether the CH4

concentration measurement at each degasification 

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 this subpart; and the 

gaseous organic concentration correction factor, if Equation 

FF-9 was required. Moisture content is required to be 

reported only if CH4 concentration is measured on a wet 

basis and volumetric flow is measured on a dry basis, if CH4

concentration 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 operating 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 days 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 location and the annual operating hours and 

(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:

(i) The number of destruction devices associated with the 

measurement location.

See preamble text for 

explanation.
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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 collection 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 considered 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 each 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 (Option 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 with 

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 GCH4 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 atmosphere 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.
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covers may include, but are not limited to, 

evapotranspiration covers, capillary barrier covers, 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 health 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. 

See 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 atmosphere 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 treatment 

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 generated 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 digester.

(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 lagoon (depth less than 2 meters).

(4) Anaerobic sludge digester.

Clarifies reporting 

requirements.
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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 CO2 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 CO2 emissions that 

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 CO2

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 CO2

emissions that would result from the complete combustion 

or oxidation of any biomass co-processed with fossil fuelbased 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 liquid 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 

exporters 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 coalto-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 shall 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-toliquid products shall also include coal-to-liquid products.

(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 

with subpart MM.
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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-toliquid 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 in § 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-toliquid 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 

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.

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 every 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 Method 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 

received 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.
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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 determine 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 reported 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-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.

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 with 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 

gravity 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.
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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 CO2 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 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. 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, ograde, and other bulk NGLs). LDCs shall estimate CO2

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 NN1

CO2. = Annual CO2 mass emissions that would result from 

the combustion or oxidation of each product “h” for 

redelivery to all recipients (metric tons).

CO2i = 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 CO2 emissions that would result from the 

complete combustion or oxidation of the product(s) 

supplied using Equation NN-2 of this section. LDCs shall 

estimate CO2 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 CO2 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, ograde, and other bulk NGLs). LDCs shall estimate CO2

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

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

NN 98.403(a)(2); 

Equation NN2

CO2. = Annual CO2 mass emissions that would result from 

the combustion or oxidation of each product “h” (metric 

tons)

CO2i = 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 NN3

CO2. = Annual CO2 mass emissions that would result from 

the combustion or oxidation of natural gas for redelivery to 

transmission pipelines or other LDCs (metric tons).

CO2j = Annual CO2 mass emissions that would result from the 

combustion or oxidation of natural gas for redelivery to 

transmission pipelines or other LDCs (metric tons).

Editorial correction.

NN 98.403(b)(1); 

Equation NN3

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

CO2. = Annual CO2 mass emissions that would result from 

the combustion or oxidation of natural gas delivered to 

each large end-user k, as defined in paragraph (b)(2)(i) of 

this section (metric tons).

CO2k = Annual CO2 mass emissions that would result from 

the combustion or oxidation of natural gas delivered to each 

large end-user k, as defined in paragraph (b)(2)(i) of this 

section (metric tons).

Editorial correction.

NN 98.403(b)(3)(i

); Equation 

NN-5a

CO2. = Annual CO2 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).

CO2l = Annual CO2 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 CO2 emission factor for natural gas 

placed into/removed from storage (MT CO2/Mscf).

EF = CO2 emission factor for natural gas placed into/removed 

from storage (MT CO2/Mscf).

Clarifies equation term.

NN 98.403(b)(3)(ii

); Equation 

NN-5b

CO2. = Annual CO2 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).

CO2n = Annual CO2 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 NN6

CO2. = Annual CO2 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).

CO2. = Annual CO2 mass emissions that would result 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).

CO2. = Annual CO2 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).

CO2. = Annual CO2 mass emissions that would result from 

the combustion or oxidation of the net change in natural 

CO2i = Annual CO2 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).

CO2j = Annual CO2 mass emissions that would result 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).

CO2k = Annual CO2 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).

CO2l = Annual CO2 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).

CO2. = Annual CO2 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).

CO2n = Annual CO2 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).

NN 98.403(c)(1)(ii

); Equation 

NN-7

CO2. = Annual CO2 mass emissions that would result from 

the combustion or oxidation of each fractionated NGL 

product “g” received from other fractionators (metric 

tons).

CO2m = 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); 

Equation NN8

CO2. = 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).

CO2i = 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 NN8

CO2. = 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).

CO2m = 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 

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.

Editorial correction.

NN 98.404(a)(3) (3) NGL fractionators shall use measurement for NGLs at 

custody tranfer 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 products 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 listed 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 fractionators) 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 volume 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 on 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 

the 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 categories. 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 supplier 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 nitrous 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 fluorinated 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 product. 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 does not include the dissociation of fluorinated 

See preamble text 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.

Pp = 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 solely 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.

Pp = Mass of fluorinated GHG, fluorinated HTF, or nitrous 

oxide produced over the period “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:

Pp = Mass of fluorinated GHG or nitrous oxide produced 

over the period “p” (metric tons).

Op = Mass of fluorinated GHG or nitrous oxide that is 

measured coming out of the production process over the 

period p (metric tons).

Up = Mass of used fluorinated GHG or 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 Equation OO-2 of this section:

Where:

Pp = Mass of fluorinated GHG, fluorinated HTF, or nitrous 

oxide produced over the period “p” (metric tons).

Op = Mass of fluorinated GHG, fluorinated HTF, or nitrous 

oxide that is measured coming out of the production process 

over the period p (metric tons).

Up = Mass of used fluorinated GHG, fluorinated HTF, or 

nitrous oxide that is added to the production process 

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 

section:

(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 the 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 transformation 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 (metric 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 fluorinated 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 this 

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 

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 or 

fluorinated HTF, the concentrations of each of the 

fluorinated GHGs or fluorinated HTFs, other than lowconcentration 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 

fluorinated 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 

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, 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 purposes 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 

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 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 

recovered, 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 fluorinated 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 changes 

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 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 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 process 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) 

because 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 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 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 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 that 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 

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 

being destroyed, you must estimate the concentrations of 

the fluorinated GHG or fluorinated 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 destroyed 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 conditions 

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 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 

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 lowconcentration 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 occurs 

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 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. 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 

process 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 relative standard deviation of the 

measured concentrations of any of the fluorinated GHGs or 

Harmonizing changes 

with proposed changes 

to 98.410.
55

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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 achieve 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 

irretrievably 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 destruction, 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 example, 

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 fluorinated 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 captured 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 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 irretrievably contaminated and are therefore 

destroyed.

....

(5) Total mass in metric tons of each fluorinated GHG, 

fluorinated HTF, or nitrous oxide sent to another 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) 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 example, fluorinated 

GHGs that are returned to the facility for reclamation but 

Harmonizing changes 

with proposed changes 

to 98.410.
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(7) Total mass in metric tons of each fluorinated GHG that 

is sent to another facility 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 transformation 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 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 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 nitrous 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 each 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 irretrievably 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 

§ 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, fluorinated 

HTF, or nitrous oxide fed into the transformation process, by 

process.

(11) Mass in metric tons of each 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 quantities (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 quantities (metric tons) of each 

fluorinated GHG or fluorinated HTF that were sent to each 

for destruction.
57

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(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 days 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 information 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 this 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 GHG 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

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

OO 98.416(c) (c) Each bulk importer 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 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 of nitrous oxide and each 

fluorinated GHG imported in bulk, including each 

fluorinated GHG constituent of the fluorinated 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 applicable, 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 transferred 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 of 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 by 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 chemical.

(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 importer.

(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 fluorinated 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 destruction, 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 contain 

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 nitrous 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 

fluorinated 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 facility 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 

quantities 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 

concentration 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 measurement 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-concentration 

constituent means a fluorinated GHG constituent of a 

fluorinated GHG product that occurs in the product in 

concentrations below 0.5 percent by mass. Lowconcentration constituents do not include fluorinated GHGs 

that are deliberately combined with the 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 GHG 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 fluorinated GHG or 

fluorinated HTF product that occurs in the product in 

concentrations below 0.5 percent by mass. Lowconcentration 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 CO2 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 CO2 stream, the most appropriate of 

the following missing data procedures shall be followed:

Editorial correction.

RR 98.446(g) None (g) Whether the CO2 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

aThe applicable climate classification is determined based 

on the annual rainfall plus the recirculated leachate 

aThe applicable climate classification is determined based on 

the annual rainfall plus the recirculated leachate application 

Editorial 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 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. 

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.

TT Footnote "b" 

to Table TT-1

None bKraft 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 CO2 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 measured volumes of CO2 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 correction.
62

Appendix 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 Categoriesa Applicable in Reporting Year 2010 and Future Years

Electricity generation units that report CO2 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 CH4 in amounts equivalent to 25,000 metric tons CO2e or 

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

Manure management systems with combined CH4 and N2O emissions in amounts equivalent to 25,000 

metric tons CO2e or more per year, as determined according to subpart JJ of this part.

Additional Source Categoriesa Applicable in Reporting Year 2011 and Future Years

Electrical transmission and distribution equipment use at facilities where the total nameplate capacity of 

SF6 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 CH4 or more per year (subpart FF).

Geologic sequestration 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 Categoriesa 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 Categoriesa 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 for §98.2(a)(4)

Supplier Categoriesa 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 CO2e or more.

(C) Exporters of an annual quantity of coal-to-liquid products that is equivalent to 25,000 

metric tons CO2e 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 CO2e or more.

(C) Exporters of an annual quantity of petroleum products and natural gas liquids that is 

equivalent to 25,000 metric tons CO2e 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 N2O, fluorinated GHG, fluorinated heat transfer fluids, and CO2 that in 

combination are equivalent to 25,000 metric tons CO2e or more.

(C) Exporters of industrial greenhouse gases with annual bulk exports of N2O, fluorinated 

GHG, fluorinated heat transfer fluids, and CO2 that in combination are equivalent to 25,000 

metric tons CO2e or more.

(D) Facilities that destroy 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 CO2.

(B) Importers of CO2 with annual bulk imports of N2O, fluorinated GHG, and CO2 that in 

combination are equivalent to 25,000 metric tons CO2e or more.

(C) Exporters of CO2 with annual bulk exports of N2O, fluorinated GHG, and CO2 that in 

combination are equivalent to 25,000 metric tons CO2e or more.

Additional Supplier Categories Applicablea in Reporting Year 2011 and Future Years

Importers and exporters of fluorinated greenhouse gases contained in pre-charged equipment or closedcell foams (subpart QQ):

(A) Importers of an annual quantity of fluorinated greenhouse gases contained in precharged equipment or closed-cell foams that is equivalent to 25,000 metric tons CO2e or 

more.

(B) Exporters of an annual quantity of fluorinated greenhouse gases contained in precharged equipment or closed-cell foams that is equivalent to 25,000 metric tons CO2e 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 CO2 Emission Factors and High Heat Values 

for Various Types of Fuel

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

Fuel type Default high heat value

Default CO2

emission

factor

Coal and coke mmBtu/short ton kg CO2/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 CO2/mmBtu

(Weighted U.S. Average) 1.026 × 10−3 53.06

Petroleum products—liquid mmBtu/gallon kg CO2/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

Propane1 0.091 62.87

Propylene2 0.091 67.77

Ethane1 0.068 59.60
66

Ethanol 0.084 68.44

Ethylene2 0.058 65.96

Isobutane1 0.099 64.94

Isobutylene1 0.103 68.86

Butane1 0.103 64.77

Butylene1 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 CO2/mmBtu

Petroleum Coke 30.00 102.41
67

Petroleum products—gaseous mmBtu/scf kg CO2/mmBtu

Propane Gas 2.516 × 10−3 61.46

Other fuels—solid mmBtu/short ton kg CO2/mmBtu

Municipal Solid Waste 9.953 90.7

Tires 28.00 85.97

Plastics 38.00 75.00

Petroleum Coke 30.00 102.41

Other fuels—gaseous mmBtu/scf kg CO2/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 Gas4 1.388 × 10−3 59.00

Biomass fuels—solid mmBtu/short ton kg CO2/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 CO2/mmBtu

Landfill Gas 0.485 × 10−3 52.07

Other Biomass Gases 0.655 × 10−3 52.07

Biomass Fuels—Liquid mmBtu/gallon kg CO2/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 their 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 default HHV and the default CO2 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 Tier 3 (Equation C-5) or Tier 4.

5

Use the following formula to calculate a wet basis HHV for use in Equation C-1: HHVw = ((100 − M)/100)*HHVd

where HHVw = wet basis HHV, M = moisture content (percent) and HHVd = 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 CH4 and N2O Emission Factors for Various 

Types of Fuel

Fuel type

Default CH4 emission 

factor (kg CH4/mmBtu)

Default N2O emission 

factor (kg N2O/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 WasteOther 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 combustion, those who fall within the IPCC “Energy Industry” category may employ a value of 

1g of CH4/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 Rates (Bijk) for 

Semiconductor Manufacturing for 150mm and 200 mm Wafer Sizes

Table I–3 to Subpart I of Part 98—Default Emission Factors (1–Uij) for Gas Utilization 

Rates (Uij) and By-Product Formation Rates (Bijk) for Semiconductor Manufacturing for 

150mm and 200 mm Wafer Sizes

Process 

type/Subtype

Process gas i

CF4 C2F6 CHF3 CH2F2C2HF5 CH3F C3F8 C4F8 NF3 SF6 C4F6 C5F8 C4F8O

ETCHING/WAFER CLEANING

1–Ui 0.81 0.720.5051 0.13 0.064 0.5170 NA 0.14 0.19 0.55 0.17 0.072 NA

BCF4 NA 0.10 0.085 0.079 0.077 NA NA 0.11 0.0040 0.13 0.13 NA NA

BC2F6 0.046 NA 0.030 0.025 0.024 0.0034NA NA 0.037 0.025 0.11 0.11 0.014 NA

BC4F6 NA NA NA NA NA NA NA NA NA NA NA NA NA

BC4F8 NA NA NA NA NA NA NA NA NA NA NA NA NA

BC3F8 NA NA NA NA NA NA NA NA NA NA NA NA NA

BC5F8 0.0012 NA 0.0012 NA NA NA NA 0.0086 NA NA NA NA NA

BCHF3 0.10 0.047 NA 0.049 NA NA

0.0034 NA 0.040 NA 0.0012 0.066 0.0039 NA

CHAMBER CLEANING

In situ plasma cleaning:
70

Process 

type/Subtype

Process gas i

CF4 C2F6 CHF3 CH2F2C2HF5 CH3F C3F8 C4F8 NF3 SF6 C4F6 C5F8 C4F8O

1–Ui 0.92 0.55 NA NA NA NA 0.40 0.10 0.18 NA NA NA 0.14

BCF4 NA 0.19 NA NA NA NA 0.20 0.11 0.050 NA NA NA 0.13

BC2F6 NA NA NA NA NA NA NA NA NA NA NA NA 0.045

BC3F8 NA NA NA NA NA NA NA NA NA NA NA NA NA

Remote plasma cleaning:

1–Ui NA NA NA NA NA NA NA NA0.018017 NA NA NA NA

BCF4 NA NA NA NA NA NA NA NA 0.015 NA NA NA NA

BC2F6 NA NA NA NA NA NA NA NA NA NA NA NA NA

BC3F8 NA NA NA NA NA NA NA NA NA NA NA NA NA

In situ thermal cleaning:

1–Ui NA NA NA NA NA NA NA NA NA NA NA NA NA

BCF4 NA NA NA NA NA NA NA NA NA NA NA NA NA

BC2F6 NA NA NA NA NA NA NA NA NA NA NA NA NA

BC3F8 NA NA NA NA NA NA NA NA NA NA NA NA NA

Notes: NA = Not applicable; i.e., there are no applicable default emission factor measurements for this gas. This does not 

necessarily imply that a particular gas is not used in or emitted from a particular process sub-type or process type.

67. 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 CH4 and N2O

Fuel

Fossil fuel-based emissions factors (kg/mmBtu HHV)

Kraft rotary lime kilns Kraft calcinersa
71

CH4 N2O CH4 N2O

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 bNA bNA

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.

ab Emission factors for kraft calciners are not available.

78. 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 collection

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).

89. 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/ora

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 inchesintermediate or interim covera 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 inchesintermediate or interim covera for 

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

rateba is less than 10 grams per square meter per day (g/m2/d)

0.35

C6: For landfills that have a soil cover of at least 24 inchesintermediate or interim covera for 

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

rateba is 10 to 70 g/m2/d

0.25

C7: For landfills that have a soil cover of at least 24 inchesintermediate or interim covera for a 

majoritygreater than 50% of the landfill area containing waste and for which the methane flux 

rateba is greater than 70 g/m2/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.

ba

Methane flux rate (in grams per square meter per day; g/m2/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/m2

/d).

K = unit conversion factor = 106

/365 (g/metric ton per days/year) or 106/366 for a leap year.

SArea = The surface area of the landfill containing waste at the beginning of the reporting year (square meters, m2

).

GCH4 = Modeled methane generation rate in reporting year from Equation HH-1 of this subpart or Equation TT-1 of 

subpart TT of this part, as applicable, except for application with Equation HH-6 of this subpart (metric 

tons CH4). For application with Equation HH-6 of this subpart, the greater of the modeled methane 

generation rate in reporting year from Equation HH-1 of this subpart or Equation TT-1 of this part, as 

applicable, and the quantity of recovered CH4 from Equation HH-4 of this subpart (metric tons CH4).

CE = Collection efficiency estimated at landfill, taking into account system coverage, operation, 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 CH4 concentration of the recovered 

gas sent to one or multiple destruction devices, then N=1.

Rn = Quantity of recovered CH4 from Equation HH-4 of this subpart for the nth measurement location (metric tons).

fRec,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).

810. Proposed Amendments to Table NN–2 to Subpart 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 CO2 emission valuefactor

(MT CO2/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 CO2/bbl are 60 °F and saturation pressure.

911. 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

(weight fraction, wet 

basis)

k

[dry 

climatea]

(yr−1)

k

[moderate 

climatea]

(yr−1)

k

[wet 

climatea]

(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 

Wastesb

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.