DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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PART 98

Subpart A— General Provision

§98.1 Purpose and scope.

(a) This part establishes mandatory greenhouse gas 

(GHG) reporting requirements for owners and operators of 

certain facilities that directly emit GHG as well as for 

certain suppliers. For suppliers, the GHGs reported are 

the quantity that would be emitted from combustion or use 

of the products supplied.

(b) Owners and operators of facilities and suppliers 

that are subject to this part must follow the requirements 

of this subpart and all applicable subparts of this part. 

If a conflict exists between a provision in subpart A and 

any other applicable subpart, the requirements of the 

applicable subpart shall take precedence.

§98.2 Who must report?

(a) The GHG reporting requirements and related 

monitoring, recordkeeping, and reporting requirements of 

this part apply to the owners and operators of any facility 

that is located in the United States or under or attached 

to the Outer Continental Shelf (as defined in 43 U.S.C. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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1331) and that meets the requirements of either paragraph 

(a)(1), (a)(2), or (a)(3) of this section; and any supplier 

that meets the requirements of paragraph (a)(4) of this 

section:

(1) A facility that contains any source category that 

is listed in Table A-3 of this subpart in any calendar year 

starting in 2010. For these facilities, the annual GHG

report must cover stationary fuel combustion sources 

(subpart C of this part), miscellaneous use of carbonates 

(subpart U of this part), and all applicable source 

categories listed in Table A-3 and Table A-4 of this 

subpart.

(2) A facility that contains any source category that 

is listed in Table A-4 of this subpart and that emits 

25,000 metric tons CO2e or more per year in combined 

emissions from stationary fuel combustion units, 

miscellaneous uses of carbonate, and all applicable source 

categories that are listed in Table A-3 and Table A-4 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 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 3 of 520

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this part), and all applicable source categories listed in 

Table A-3 and Table A-4 of this subpart. 

(3) A facility that in any calendar year starting in 

2010 meets all three of the conditions listed in this 

paragraph (a)(3). For these facilities, the annual GHG 

report must cover emissions from stationary fuel combustion 

sources only. 

(i) The facility does not meet the requirements of 

either paragraph (a)(1) or (a)(2) of this section.

(ii) The aggregate maximum rated heat input capacity 

of the stationary fuel combustion units at the facility is 

30 mmBtu/hr or greater.

(iii) The facility emits 25,000 metric tons CO2e or 

more per year in combined emissions from all stationary 

fuel combustion sources.

(4) A supplier that is listed in Table A-5 of this 

subpart. For these suppliers, the annual GHG report must 

cover all applicable products for which calculation 

methodologies are provided in the subparts listed in Table 

A-5 of this subpart.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(5) Research and development activities are not 

considered to be part of any source category defined in 

this part. 

(b) To calculate GHG emissions for comparison to the 

25,000 metric ton CO2e per year emission threshold in 

paragraph (a)(2) of this section, the owner or operator 

shall calculate annual CO2e emissions, as described in 

paragraphs (b)(1) through (b)(4) of this section. 

(1) Calculate the annual emissions of CO2, CH4, N2O,

and each fluorinated GHG in metric tons from all applicable 

source categories listed in paragraph (a)(2) of this 

section. The GHG emissions shall be calculated using the 

calculation methodologies specified in each applicable 

subpart and available company records. Include emissions 

from only those gases listed in Table A-1 of this subpart. 

(2) For each general stationary fuel combustion unit, 

calculate the annual CO2 emissions in metric tons using any 

of the four calculation methodologies specified in 

§98.33(a). Calculate the annual CH4 and N2O emissions from 

the stationary fuel combustion sources in metric tons using 

the appropriate equation in §98.33(c). Exclude carbon 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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dioxide emissions from the combustion of biomass, but 

include emissions of CH4 and N2O from biomass combustion. 

(3) For miscellaneous uses of carbonate, calculate the 

annual CO2 emissions in metric tons using the procedures 

specified in subpart U of this part.

(4) Sum the emissions estimates from paragraphs 

(b)(1), (b)(2), and (b)(3) of this section for each GHG and 

calculate metric tons of CO2e using Equation A-1 of this 

section.







n

i 1 i

x GWP ie GHG 2CO (Eq. A-1)

Where: 

CO2e = Carbon dioxide equivalent, metric tons/year.

GHGi = Mass emissions of each greenhouse gas listed in 

Table A-1 of this subpart, metric tons/year.

GWPi = Global warming potential for each greenhouse gas 

from Table A-1 of this subpart.

n = The number of greenhouse gases emitted.

(5) For purpose of determining if an emission 

threshold has been exceeded, include in the emissions 

calculation any CO2 that is captured for transfer off site.

(c) To calculate GHG emissions for comparison to the 

25,000 metric ton CO2e/year emission threshold for 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 6 of 520

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stationary fuel combustion under paragraph (a)(3) of this 

section, calculate CO2, CH4, and N2O emissions from each

stationary fuel combustion unit by following the methods 

specified in paragraph (b)(2) of this section. Then, 

convert the emissions of each GHG to metric tons CO2e per 

year using Equation A-1 of this section, and sum the 

emissions for all units at the facility.

(d) To calculate GHG quantities for comparison to the 

25,000 metric ton CO2 per year threshold for importers and 

exporters of coal-to-liquid products under paragraph (a)(4)

of this section, calculate the mass in metric tons per year 

of CO2 that would result from the complete combustion or 

oxidation of the quantity of coal-to-liquid products that 

are imported during the reporting year and, that are 

exported during the reporting year. Compare the imported 

quantities and the exported quantities separately to the 

25,000 metric ton CO2 per year threshold. Calculate the 

quantities using the methodology specified in subpart LL of 

this part. 

(e) To calculate GHG quantities for comparison to the 

25,000 metric ton CO2e per year threshold for importers and 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 7 of 520

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exporters of petroleum products and natural gas liquids

under paragraph (a)(4) of this section, calculate the mass 

in metric tons per year of CO2 that would result from the 

complete combustion or oxidation of the combined volume of 

petroleum products and natural gas liquids that are 

imported during the reporting year and that are exported 

during the reporting year. Compare the imported quantities 

and the exported quantities separately to the 25,000 metric 

ton CO2 per year threshold. Calculate the quantities using 

the methodology specified in subpart MM of this part.

(f) To calculate GHG quantities for comparison to the 

25,000 metric ton CO2e per year threshold under paragraph 

(a)(4) of this section for importers and exporters of 

industrial greenhouse gases and for importers and exporters 

of CO2, the owner or operator shall calculate the mass in 

metric tons per year of CO2e imports and exports as 

described in paragraphs (f)(1) through (f)(3) of this 

section. Compare the imported quantities and the exported 

quantities separately to the 25,000 metric ton CO2 per year 

threshold.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(1) Calculate the mass in metric tons per year of CO2, 

N2O, and each fluorinated GHG that is imported and the mass 

in metric tons per year of CO2, N2O, and each fluorinated 

GHG that is exported during the year. Include only those 

gases listed in Table A-1 of this subpart. 

(2) Convert the mass of each imported and each GHG 

exported from paragraph (f)(1) of this section to metric 

tons of CO2e using Equation A-1 of this section.

(3) Sum the total annual metric tons of CO2e in 

paragraph (f)(2) of this section for all imported GHGs. Sum 

the total annual metric tons of CO2e in paragraph (f)(2) of 

this section for all exported GHGs. 

(g) If a capacity or generation reporting threshold in 

paragraph (a)(1) of this section applies, the owner or 

operator shall review the appropriate records and perform 

any necessary calculations to determine whether the 

threshold has been exceeded. 

(h) An owner or operator of a facility or supplier 

that does not meet the applicability requirements of 

paragraph (a) of this section is not subject to this rule. 

Such owner or operator would become subject to the rule and 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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reporting requirements, if a facility or supplier exceeds 

the applicability requirements of paragraph (a) of this 

section at a later time pursuant to §98.3(b)(3). Thus, the 

owner or operator should reevaluate the applicability to 

this part (including the revising of any relevant emissions 

calculations or other calculations) whenever there is any 

change that could cause a facility or supplier to meet the 

applicability requirements of paragraph (a) of this 

section. Such changes include but are not limited to 

process modifications, increases in operating hours, 

increases in production, changes in fuel or raw material 

use, addition of equipment, and facility expansion.

(i) Except as provided in this paragraph, once a 

facility or supplier is subject to the requirements of this 

part, the owner or operator must continue for each year 

thereafter to comply with all requirements of this part, 

including the requirement to submit annual GHG reports, 

even if the facility or supplier does not meet the 

applicability requirements in paragraph (a) of this section 

in a future year.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(1) If reported emissions are less than 25,000 metric 

tons CO2e per year for five consecutive years, then the 

owner or operator may discontinue complying with this part 

provided that the owner or operator submits a notification 

to the Administrator that announces the cessation of 

reporting and explains the reasons for the reduction in 

emissions. The notification shall be submitted no later 

than March 31 of the year immediately following the fifth 

consecutive year of emissions less than 25,000 tons CO2e per 

year. The owner or operator must maintain the corresponding 

records required under §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.

(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 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 11 of 520

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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.

(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 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 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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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.

(j) Table A-2 of this subpart provides a conversion 

table for some of the common units of measure used in part 

98.

§98.3 What are the general monitoring, reporting, 

recordkeeping and verification requirements of this part?

The owner or operator of a facility or supplier that 

is subject to the requirements of this part must submit GHG 

reports to the Administrator, as specified in this section.

(a) General. Except as provided in paragraph (d) of 

this section, follow the procedures for emission 

calculation, monitoring, quality assurance, missing data, 

recordkeeping, and reporting that are specified in each 

relevant subpart of this part.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(b) Schedule. The annual GHG report for reporting 

year 2010 must be submitted no later than September 30, 

2011. The annual report for reporting years 2011 and 

beyond must be submitted no later than March 31 of each 

calendar year for GHG emissions in the previous calendar 

year, except as provided in paragraph (b)(1) of this 

section. 

(1) For reporting year 2011, GHG information required 

by the subparts listed in paragraphs (b)(1)(i) through 

(b)(1)(xii) of this section must be submitted no later than 

September 28, 2012. This reporting date applies only to 

the data reporting requirements identified in the listed 

subparts and does not affect data reporting requirements of 

other subparts that apply to a facility or supplier. 

(i) Electronics Manufacturing (subpart I).

(ii) Fluorinated Gas Production (subpart L).

(iii) Magnesium Production (subpart T).

(iv) Petroleum and Natural Gas Systems (subpart W).

(v) Use of Electric Transmission and Distribution 

Equipment (subpart DD).

(vi) Underground Coal Mines (subpart FF).
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(vii) Industrial Wastewater Treatment (subpart II).

(viii) Imports and Exports of Equipment Pre–charged 

with Fluorinated GHGs or Containing Fluorinated GHGs in 

Closed–cell Foams (subpart QQ).

(ix) Geologic Sequestration of Carbon Dioxide (subpart 

RR).

(x) Manufacture of Electric Transmission and 

Distribution (subpart SS).

(xi) Industrial Waste Landfills (subpart TT).

(xii) Injection of Carbon Dioxide (Subpart UU).

(2) For a new facility or supplier that begins

operation on or after January 1, 2010 and becomes subject 

to the rule in the year that it becomes operational, report 

emissions beginning with the first operating month and 

ending on December 31 of that year. Each subsequent annual 

report must cover emissions for the calendar year, 

beginning on January 1 and ending on December 31.

(3) For any facility or supplier that becomes subject 

to this rule because of a physical or operational change 

that is made after January 1, 2010, report emissions for 

the first calendar year in which the change occurs, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 15 of 520

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beginning with the first month of the change and ending on 

December 31 of that year. For a facility or supplier that 

becomes subject to this rule solely because of an increase 

in hours of operation or level of production, the first 

month of the change is the month in which the increased 

hours of operation or level of production, if maintained 

for the remainder of the year, would cause the facility or 

supplier to exceed the applicable threshold. Each 

subsequent annual report must cover emissions for the 

calendar year, beginning on January 1 and ending on 

December 31.

(4) Unless otherwise stated, if the final day of any 

time period falls on a weekend or a Federal holiday, the 

time period shall be extended to the next business day.

 

(c) Content of the annual report. Except as provided 

in paragraph (d) of this section, each annual GHG report 

shall contain the following information:

(1) Facility name or supplier name (as appropriate), 

and physical street address of the facility or supplier, 

including the city, State, and zip code.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(2) Year and months covered by the report.

(3) Date of submittal.

(4) For facilities, except as otherwise provided in 

paragraph (c)(12) of this section, report annual emissions 

of CO2,CH4, N2O, and each fluorinated GHG (as defined in § 

98.6) as follows.

(i) Annual emissions (excluding biogenic CO2) 

aggregated for all GHG from all applicable source 

categories, expressed in metric tons of CO2e calculated 

using Equation A–1 of this subpart.

(ii) Annual emissions of biogenic CO2 aggregated for 

all applicable source categories, expressed in metric tons.

(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.

(A) Biogenic CO2.

(B) CO2 (excluding biogenic CO2).

(C) CH4.

(D) N2O.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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(E) Each fluorinated GHG (including those not listed 

in Table A-1 of this subpart).

(iv) Except as provided in paragraph(c)(4)(vii) of 

this section, emissions and other data for individual 

units, processes, activities, and operations as specified 

in the “Data reporting requirements” section of each 

applicable subpart of this part.

(v) Indicate (yes or no) whether reported emissions 

include emissions from a cogeneration unit located at the 

facility.

(vi) Applicable source categories means stationary 

fuel combustion sources (subpart C of this part),

miscellaneous use of carbonates(subpart U of this part), 

and all of the source categories listed in Table A–3

and Table A–4 of this subpart present at the facility.

(vii) The owner or operator of a facility is not 

required to report the data elements specified in Table A–6 

of this subpart for calendar year 2010 until September 30, 

2011.

(viii) When applying paragraph (c)(4)(i) of this 

section to fluorinated GHGs, calculate and report CO2e for 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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only those fluorinated GHGs listed in Table A–1 of this 

subpart.

(5) For suppliers, report annual quantities of CO2, CH4, 

N2O, and each fluorinated GHG (as defined in §98.6) that 

would be emitted from combustion or use of the products 

supplied, imported, and exported during the year. Calculate 

and report quantities at the following levels:

(i) Total quantity of GHG aggregated for all GHG from 

all applicable supply categories in Table A-5 of this 

subpart and expressed in metric tons of CO2e calculated 

using Equation A-1 of this subpart. For fluorinated GHGs,

calculate and report CO2e for only those fluorinated GHGs 

listed in Table A–1 of this subpart.

(ii) Quantity of each GHG from each applicable supply 

category in Table A-5 of this subpart, expressed in metric 

tons of each GHG. For fluorinated GHG, report quantities of 

all fluorinated GHG, including those not listed in Table A1 of this subpart.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(iii) Any other data specified in the “Data reporting 

requirements” section of each applicable subpart of this 

part. 

(6) A written explanation, as required under §98.3(e), 

if you change emission calculation methodologies during the 

reporting period.

(7) A brief description of each “best available 

monitoring method” used, the parameter measured using the 

method, and the time period during which the “best 

available monitoring method” was used, if applicable.

(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.

(9) A signed and dated certification statement 

provided by the designated representative of the owner or 

operator, according to the requirements of §98.4(e)(1).

(10) NAICS code(s) that apply to the facility or 

supplier. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(i) Primary NAICS code. Report the NAICS code that 

most accurately describes the facility or supplier’s 

primary product/activity/ service. The primary 

product/activity/ service is the principal source of 

revenue for the facility or supplier. A facility or 

supplier that has two distinct 

products/activities/services providing comparable revenue 

may report a second primary NAICS code.

(ii) Additional NAICS code(s). Report all additional 

NAICS codes that describe all 

product(s)/activity(s)/service(s) at the facility or 

supplier that are not related to the principal source of 

revenue.

(11) Legal name(s) and physical address(es) of 

the highest-level United States parent company(s) of the 

owners (or operators?) of the facility or supplier and 

the percentage of ownership interest for each listed 

parent company as of December 31 of the year for which 

data are being reported according to the following 

instructions:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(i) If the facility or supplier is entirely owned by a 

single United States company that is not owned by another 

company, provide that company’s legal name and physical 

address as the United States parent company and report 

100 percent ownership.

(ii) If the facility or supplier is entirely owned by 

a single United States company that is, itself, owned by 

another company (e.g., it is a division or subsidiary of a 

higher-level company), provide the legal name and 

physical address of the highest-level company in the 

ownership hierarchy as the United States parent company 

and report 100 percent ownership.

(iii) If the facility or supplier is owned by more 

than one United States company (e.g., company A owns 40 

percent, company B owns 35 percent, and company C owns 

25 percent), provide the legal names and physical 

addresses of all the highest-level companies with an 

ownership interest as the United States parent 

companies, and report the percent ownership of each 

company.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 22 of 520

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(iv) If the facility or supplier is owned by a joint 

venture or a cooperative, the joint venture or cooperative 

is its own United States parent company. Provide the 

legal name and physical address of the joint venture or 

cooperative as the United States parent company, and 

report 100 percent ownership by the joint venture or 

cooperative.

(v) If the facility or supplier is entirely owned by a 

foreign company, provide the legal name and physical 

address of the foreign company’s highest-level company 

based in the United States as the United States parent 

company, and report 100 percent ownership.

(vi) If the facility or supplier is partially owned 

by a foreign company and partially owned by one or more 

U.S. companies, provide the legal name and physical 

address of the foreign company’s highest-level company 

based in the United States, along with the legal names 

and physical addresses of the other U.S. parent 

companies, and report the percent ownership of each of 

these companies.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(vii) If the facility or supplier is a federally 

owned facility, report “U.S. Government” and and do not 

report physical address or percent ownership.

(12) For the 2010 reporting year only, facilities 

that have “part 75 units” (i.e., units that are subject 

to subpart D of this part or units that use the methods 

in part 75 of this chapter to quantify CO2 mass emissions 

in accordance with 98.33(a)(5)) must report annual GHG 

emissions either in full accordance with paragraphs

(c)(4)(i) through (c)(4)(iii) of this section or in full 

accordance with paragraphs (c)(12)(i) through 

(c)(12)(iii) of this section. If the latter reporting 

option is chosen, you must report:

(i) Annual emissions aggregated for all GHG from all 

applicable source categories, expressed in metric tons of 

CO2e calculated using Equation A–1 of this subpart. You 

must include biogenic CO2 emissions from part 75 units in 

these annual emissions, but exclude biogenic CO2 

emissions from any nonparty 75 units and other source 

categories. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 24 of 520

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(ii) Annual emissions of biogenic CO2, expressed in 

metric tons (excluding biogenic CO2 emissions from part 

75 units), aggregated for all applicable source 

categories. 

(iii) Annual emissions from each applicable source 

category, expressed in metric tons of each applicable GHG 

listed in paragraphs (c)(12)(iii)(A) through 

c)(12)(iii)(E) of this section. 

(A) Biogenic CO2 (excluding biogenic CO2 emissions 

from part 75 units).

(B) CO2. You must include biogenic CO2 emissions 

from part 75 units in these totals and exclude biogenic

CO2 emissions from other non-part 75 units and other 

source categories.

(C) CH4.

(D) N2O.

(E) Each fluorinated GHG (including those not listed 

in Table A–1 of this subpart).

(d) Special provisions for reporting year 2010.

(1) Best available monitoring methods. During January 

1, 2010 through March 31, 2010, owners or operators may use 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 25 of 520

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best available monitoring methods for any parameter (e.g., 

fuel use, daily carbon content of feedstock by process 

line) that cannot reasonably be measured according to the 

monitoring and QA/QC requirements of a relevant subpart. 

The owner or operator must use the calculation 

methodologies and equations in the “Calculating GHG 

Emissions” sections of each relevant subpart, but may use 

the best available monitoring method for any parameter for 

which it is not reasonably feasible to acquire, install, 

and operate a required piece of monitoring equipment by 

January 1, 2010. Starting no later than April 1, 2010, the 

owner or operator must discontinue using best available 

methods and begin following all applicable monitoring and 

QA/QC requirements of this part, except as provided in 

paragraphs (d)(2) and (d)(3) of this section. Best 

available monitoring methods means any of the following 

methods specified in this paragraph:

(i) Monitoring methods currently used by the facility 

that do not meet the specifications of an relevant subpart.

(ii) Supplier data.

(iii) Engineering calculations.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 26 of 520

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(iv) Other company records.

(2) Requests for extension of the use of best 

available monitoring methods. The owner or operator may 

submit a request to the Administrator to use one or more 

best available monitoring methods beyond March 31, 2010.

(i) Timing of request. The extension request must be 

submitted to EPA no later than 30 days after the effective 

date of the GHG reporting rule.

(ii) Content of request. Requests must contain the 

following information:

(A) A list of specific item of monitoring 

instrumentation for which the request is being made and the 

locations where each piece of monitoring instrumentation 

will be installed.

(B) Identification of the specific rule requirements 

(by rule subpart, section, and paragraph numbers) for which 

the instrumentation is needed. 

(C) A description of the reasons why the needed 

equipment could not be obtained and installed before April 

1, 2010.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(D) If the reason for the extension is that the 

equipment cannot be purchased and delivered by April 1, 

2010, include supporting documentation such as the date the 

monitoring equipment was ordered, investigation of 

alternative suppliers and the dates by which alternative 

vendors promised delivery, backorder notices or unexpected 

delays, descriptions of actions taken to expedite delivery, 

and the current expected date of delivery.

(E) If the reason for the extension is that the 

equipment cannot be installed without a process unit 

shutdown, include supporting documentation demonstrating 

that it is not practicable to isolate the equipment and 

install the monitoring instrument without a full process 

unit shutdown. Include the date of the most recent process 

unit shutdown, the frequency of shutdowns for this process 

unit, and the date of the next planned shutdown during 

which the monitoring equipment can be installed. If there 

has been a shutdown or if there is a planned process unit 

shutdown between promulgation of this part and April 1, 

2010, include a justification of why the equipment could 

not be obtained and installed during that shutdown.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 28 of 520

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(F) A description of the specific actions the facility 

will take to obtain and install the equipment as soon as 

reasonably feasible and the expected date by which the 

equipment will be installed and operating. 

(iii) Approval criteria. To obtain approval, the owner 

or operator must demonstrate to the Administrator’s 

satisfaction that it is not reasonably feasible to acquire, 

install, and operate a required piece of monitoring 

equipment by April 1, 2010. The use of best available 

methods will not be approved beyond December 31, 2010.

(3) Abbreviated emissions report for facilities 

containing only general stationary fuel combustion sources. 

In lieu of the report required by paragraph (c) of this 

section, the owner or operator of an existing facility that 

is in operation on January 1, 2010 and that meets the 

conditions of §98.2 (a)(3) may submit an abbreviated GHG 

report for the facility for GHGs emitted in 2010. The 

abbreviated report must be submitted by March 31, 2011. An 

owner or operator that submits an abbreviated report must 

submit a full GHG report according to the requirements of 

paragraph (c) of this section beginning in calendar year 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 29 of 520

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2012. The abbreviated facility report must include the 

following information:

(i) Facility name and physical street address

including the city, state, and zip code.

(ii) The year and months covered by the report.

(iii) Date of submittal.

(iv) Total facility GHG emissions aggregated for all 

stationary fuel combustion units calculated according to 

any method specified in §98.33(a) and expressed in metric 

tons of CO2, CH4, N2O, and CO2e. 

(v) Any facility operating data or process information 

used for the GHG emission calculations. 

(vi) A signed and dated certification statement 

provided by the designated representative of the owner or 

operator, according to the requirements of paragraph (e)(1)

of this section.

(e) Emission calculations. In preparing the GHG 

report, you must use the calculation methodologies

specified in the relevant subparts, except as specified in 

paragraph (d) of this section. For each source category, 

you must use the same calculation methodology throughout a
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 30 of 520

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reporting period unless you provide a written explanation 

of why a change in methodology was required. 

(f) Verification. To verify the completeness and 

accuracy of reported GHG emissions, the Administrator may 

review the certification statements described in paragraphs 

(c)(9) and (d)(3)(vi) of this section and any other 

credible evidence, in conjunction with a comprehensive 

review of the GHG reports and periodic audits of selected 

reporting facilities. Nothing in this section prohibits the 

Administrator from using additional information to verify 

the completeness and accuracy of the reports.

(g) Recordkeeping. An owner or operator that is 

required to report GHGs under this part must keep records 

as specified in this paragraph. Retain all required records 

for at least 3 years from the date of submission of the 

annual GHG report for the reporting year in which the 

record was generated. The records shall be kept in an 

electronic or hard-copy format (as appropriate) and 

recorded in a form that is suitable for expeditious 

inspection and review. Upon request by the Administrator, 

the records required under this section must be made 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 31 of 520

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available to EPA. Records may be retained off site if the 

records are readily available for expeditious inspection 

and review. For records that are electronically generated 

or maintained, the equipment or software necessary to read 

the records shall be made available, or, if requested by 

EPA, electronic records shall be converted to paper 

documents. You must retain the following records, in 

addition to those records prescribed in each applicable 

subpart of this part:

(1) A list of all units, operations, processes, and 

activities for which GHG emission were calculated.

(2) The data used to calculate the GHG emissions for 

each unit, operation, process, and activity, categorized by 

fuel or material type. These data include but are not 

limited to the following information in this paragraph 

(g)(2):

(i) The GHG emissions calculations and methods used.

(ii) Analytical results for the development of sitespecific emissions factors.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 32 of 520

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(iii) The results of all required analyses for high 

heat value, carbon content, and other required fuel or 

feedstock parameters.

(iv) Any facility operating data or process 

information used for the GHG emission calculations.

(3) The annual GHG reports.

(4) Missing data computations. For each missing data 

event, also retain a record of the cause of the event and 

the corrective actions taken to restore malfunctioning 

monitoring equipment.

(5) A written GHG Monitoring Plan. 

(i) At a minimum, the GHG Monitoring Plan shall 

include the elements listed in this paragraph (g)(5)(i).

(A) Identification of positions of responsibility 

(i.e., job titles) for collection of the emissions data.

(B) Explanation of the processes and methods used to 

collect the necessary data for the GHG calculations.

(C) Description of the procedures and methods that are 

used for quality assurance, maintenance, and repair of all 

continuous monitoring systems, flow meters, and other 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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instrumentation used to provide data for the GHGs reported 

under this part.

(ii) The GHG Monitoring Plan may rely on references to 

existing corporate documents (e.g., standard operating 

procedures, quality assurance programs under appendix F to 

40 CFR part 60 or appendix B to 40 CFR part 75, and other 

documents) provided that the elements required by paragraph 

(g)(5)(i) of this section are easily recognizable.

(iii) The owner or operator shall revise the GHG 

Monitoring Plan as needed to reflect changes in production 

processes, monitoring instrumentation, and quality 

assurance procedures; or to improve procedures for the 

maintenance and repair of monitoring systems to reduce the 

frequency of monitoring equipment downtime.

(iv) Upon request by the Administrator, the owner or 

operator shall make all information that is collected in 

conformance with the GHG Monitoring Plan available for 

review during an audit. Electronic storage of the 

information in the plan is permissible, provided that the 

information can be made available in hard copy upon request 

during an audit.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 34 of 520

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(6) The results of all required certification and 

quality assurance tests of continuous monitoring systems, 

fuel flow meters, and other instrumentation used to provide 

data for the GHGs reported under this part.

(7) Maintenance records for all continuous monitoring 

systems, flow meters, and other instrumentation used to 

provide data for the GHGs reported under this part.

(h) Annual GHG report revisions.

(1) The owner or operator shall submit a revised 

annual GHG report within 45 days of discovering that an 

annual GHG report that the owner or operator previously 

submitted contains one or more substantive errors. The 

revised report must correct all substantive errors.

(2) The Administrator may notify the owner or operator 

in writing that an annual GHG report previously submitted 

by the owner or operator contains one or more substantive 

errors. Such notification will identify each such 

substantive error. The owner or operator shall, within 45 

days of receipt of the notification, either resubmit the 

report that, for each identified substantive error, 

corrects the identified substantive error (in accordance 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 35 of 520

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with the applicable requirements of this part) or provide 

information demonstrating that the previously submitted 

report does not contain the identified substantive error or 

that the identified error is not a substantive error.

(3) A substantive error is an error that impacts the 

quantity of GHG emissions reported or otherwise prevents 

the reported data from being validated or verified.

(4) Notwithstanding paragraphs (h)(1) and (h)(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 (h)(2) of this 

section. If the Administrator receives a request for 

extension of the 45-day period, by e-mail to an address 

prescribed by the Administrator, at least two business days 

prior to the expiration of the 45-day period, and the 

Administrator does not respond to the request by the end of 

such period, the extension request is deemed to be 

automatically granted for 30 more days. During the 

automatic 30-day extension, the Administrator will 

determine what extension, if any, beyond the automatic 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 36 of 520

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extension is reasonable and will provide any such 

additional extension.

(5) The owner or operator shall retain documentation 

for 3 years to support any revision made to an annual GHG 

report.

(i) Calibration accuracy requirements. The owner or 

operator of a facility or supplier that is subject to the 

requirements of this part must meet the applicable flow 

meter calibration and accuracy requirements of this 

paragraph (i). The accuracy specifications in this 

paragraph (i) do not apply where either the use of company 

records (as defined in §98.6) or the use of “best available

information” is specified in an applicable subpart of this 

part to quantify fuel usage and/or other parameters. 

Further, the provisions of this paragraph (i) do not apply 

to stationary fuel combustion units that use the 

methodologies in part 75 of this chapter to calculate 

CO2mass emissions.

(1) Except as otherwise provided in paragraphs (i)(4) 

through (i)(6) of this section, flow meters that measure 

liquid and gaseous fuel feed rates, process stream flow 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 37 of 520

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rates, or feedstock flow rates and provide data for the GHG 

emissions calculations shall be calibrated prior to April 

1, 2010 using the procedures specified in this paragraph 

(i) when such calibration is specified in a relevant 

subpart of this part. Each of these flow meters shall meet 

the applicable accuracy specification in paragraph (i)(2) 

or (i)(3) of this section. All other measurement devices ( 

e.g., weighing devices) that are required by a relevant 

subpart of this part, and that are used to provide data for 

the GHG emissions calculations, shall also be calibrated 

prior to April 1, 2010; however, the accuracy 

specifications in paragraphs (i)(2) and (i)(3) of this 

section do not apply to these devices. Rather, each of 

these measurement devices shall be calibrated to meet the 

accuracy requirement specified for the device in the 

applicable subpart of this part, or, in the absence of such 

accuracy requirement, the device must be calibrated to an 

accuracy within the appropriate error range for the 

specific measurement technology, based on an applicable 

operating standard, including but not limited to 

manufacturer's specifications and industry standards. The 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 38 of 520

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procedures and methods used to quality-assure the data from 

each measurement device shall be documented in the written 

monitoring plan, pursuant to paragraph (g)(5)(i)(C) of this 

section.

(i) All flow meters and other measurement devices that 

are subject to the provisions of this paragraph (i) must be 

calibrated according to one of the following: You may use 

the manufacturer's recommended procedures; an appropriate 

industry consensus standard method; or a method specified 

in a relevant subpart of this part. The calibration 

method(s) used shall be documented in the monitoring plan 

required under paragraph (g) of this section.

(ii) For facilities and suppliers that become subject 

to this part after April 1, 2010, all flow meters and other 

measurement devices (if any) that are required by the 

relevant subpart(s) of this part to provide data for the 

GHG emissions calculations shall be installed no later than 

the date on which data collection is required to begin 

using the measurement device, and the initial 

calibration(s) required by this paragraph (i) (if any) 

shall be performed no later than that date.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 39 of 520

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(iii) Except as otherwise provided in paragraphs 

(i)(4) through (i)(6) of this section, subsequent 

recalibrations of the flow meters and other measurement 

devices subject to the requirements of this paragraph (i) 

shall be performed at one of the following frequencies:

(A) You may use the frequency specified in each

applicable subpart of this part.

(B) You may use the frequency recommended by the 

manufacturer or by an industry consensus standard practice, 

if no recalibration frequency is specified in an applicable 

subpart.

(2) Perform all flow meter calibration at measurement 

points that are representative of the normal operating 

range of the meter. Except for the orifice, nozzle, and 

venturi flow meters described in paragraph (i)(3) of this 

section, calculate the calibration error at each 

measurement point using Equation A–2 of this section. The 

terms “R” and “A” in Equation A–2 must be expressed in 

consistent units of measure ( e.g., gallons/minute, ft3

/min). The calibration error at each measurement point 

shall not exceed 5.0 percent of the reference value.
DRAFT -- This draft only contains redline/strikeout text.

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Draft – Deliberative 

Where:

CE = Calibration error (%).

R = Reference value.

A = Flow meter response to the reference value.

(3) For orifice, nozzle, and venturi flow meters, the 

initial quality assurance consists of in

of the differential pressure (delta

temperature transmitters.

(i) Calibrate each transmitter at a zero point and at 

least one upscale point. Fixed reference points, such as 

the freezing point of water, may be used for temperature 

transmitter calibrations. Calculate the calibra

of each transmitter at each measurement point, using 

Equation A–3 of this subpart. The terms “R,” “A,” and “FS” 

in Equation A–3 of this subpart must be in consistent units 

of measure (e.g., 

degrees). For each 

measurement point shall not exceed 2.0 percent of full

scale. Alternatively, the results are acceptable if the sum 

This draft only contains redline/strikeout text.

ment is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

ny person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 40 of 520

Deliberative – Do Not Cite, Quote, or Release

CE = Calibration error (%).

R = Reference value.

A = Flow meter response to the reference value.

(3) For orifice, nozzle, and venturi flow meters, the 

initial quality assurance consists of in-situ calibration 

of the differential pressure (delta-P), total pressure, and 

temperature transmitters.

(i) Calibrate each transmitter at a zero point and at 

least one upscale point. Fixed reference points, such as 

the freezing point of water, may be used for temperature 

transmitter calibrations. Calculate the calibration error 

of each transmitter at each measurement point, using 

3 of this subpart. The terms “R,” “A,” and “FS” 

3 of this subpart must be in consistent units 

, milliamperes, inches of water, psi, 

degrees). For each transmitter, the CE value at each 

measurement point shall not exceed 2.0 percent of full

scale. Alternatively, the results are acceptable if the sum 

This draft only contains redline/strikeout text. This 

ment is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

ny person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

t Cite, Quote, or Release

A = Flow meter response to the reference value.

(3) For orifice, nozzle, and venturi flow meters, the 

situ calibration 

pressure, and 

(i) Calibrate each transmitter at a zero point and at 

least one upscale point. Fixed reference points, such as 

the freezing point of water, may be used for temperature 

tion error 

of each transmitter at each measurement point, using 

3 of this subpart. The terms “R,” “A,” and “FS” 

3 of this subpart must be in consistent units 

milliamperes, inches of water, psi, 

transmitter, the CE value at each 

measurement point shall not exceed 2.0 percent of fullscale. Alternatively, the results are acceptable if the sum 
DRAFT -- This draft only contains redline/strikeout text.

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Draft – Deliberative 

of the calculated CE values for the three transmitt

each calibration level (

upscale level) does not exceed 6.0 percent.

Where:

CE = Calibration error (%).

R = Reference value.

A = Transmitter response to the reference value.

FS = Full-scale value of the transmitter.

(ii) In cases where there are only two transmitters 

i.e., differential pressure and either temperature or total 

pressure) in the immediate vicinity of the flow meter's 

primary element (

only a differential pressure transmitter in close proximity 

to the primary ele

transmitters to a CE of 2.0 percent or less at each 

measurement point is still required, in accordance with 

paragraph (i)(3)(i) of this section; alternatively, when 

two transmitters are calibrated, the results are accept

if the sum of the CE values for the two transmitters at 

This draft only contains redline/strikeout text.

ment is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

ny person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 41 of 520

Deliberative – Do Not Cite, Quote, or Release

of the calculated CE values for the three transmitt

each calibration level (i.e., at the zero level a

upscale level) does not exceed 6.0 percent.

CE = Calibration error (%).

R = Reference value.

A = Transmitter response to the reference value.

scale value of the transmitter.

(ii) In cases where there are only two transmitters 

differential pressure and either temperature or total 

pressure) in the immediate vicinity of the flow meter's 

primary element (e.g., the orifice plate), or when there is 

only a differential pressure transmitter in close proximity 

to the primary element, calibration of these existing 

transmitters to a CE of 2.0 percent or less at each 

measurement point is still required, in accordance with 

paragraph (i)(3)(i) of this section; alternatively, when 

two transmitters are calibrated, the results are accept

if the sum of the CE values for the two transmitters at 

This draft only contains redline/strikeout text. This 

ment is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

ny person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

t Cite, Quote, or Release

of the calculated CE values for the three transmitters at 

at the zero level and at each 

A = Transmitter response to the reference value.

(ii) In cases where there are only two transmitters ( 

differential pressure and either temperature or total 

pressure) in the immediate vicinity of the flow meter's 

the orifice plate), or when there is 

only a differential pressure transmitter in close proximity 

ment, calibration of these existing 

transmitters to a CE of 2.0 percent or less at each 

measurement point is still required, in accordance with 

paragraph (i)(3)(i) of this section; alternatively, when 

two transmitters are calibrated, the results are acceptable 

if the sum of the CE values for the two transmitters at 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 42 of 520

Draft – Deliberative – Do Not Cite, Quote, or Release

each calibration level does not exceed 4.0 percent. 

However, note that installation and calibration of an 

additional transmitter (or transmitters) at the flow 

monitor location to measure temperature or total pressure 

or both is not required in these cases. Instead, you may 

use assumed values for temperature and/or total pressure, 

based on measurements of these parameters at a remote 

location (or locations), provided that the following 

conditions are met:

(A) You must demonstrate that measurements at the 

remote location(s) can, when appropriate correction factors 

are applied, reliably and accurately represent the actual 

temperature or total pressure at the flow meter under all 

expected ambient conditions.

(B) You must make all temperature and/or total 

pressure measurements in the demonstration described in 

paragraph (i)(3)(ii)(A) of this section with calibrated 

gauges, sensors, transmitters, or other appropriate 

measurement devices. At a minimum, calibrate each of these 

devices to an accuracy within the appropriate error range 

for the specific measurement technology, according to one 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 43 of 520

Draft – Deliberative – Do Not Cite, Quote, or Release

of the following. You may calibrate using a manufacturer's 

specification or an industry consensus standard.

(C) You must document the methods used for the 

demonstration described in paragraph (i)(3)(ii)(A) of this 

section in the written GHG Monitoring Plan under paragraph 

(g)(5)(i)(C) of this section. You must also include the 

data from the demonstration, the mathematical 

correlation(s) between the remote readings and actual flow 

meter conditions derived from the data, and any supporting 

engineering calculations in the GHG Monitoring Plan. You 

must maintain all of this information in a format suitable 

for auditing and inspection.

(D) You must use the mathematical correlation(s) 

derived from the demonstration described in paragraph 

(i)(3)(ii)(A) of this section to convert the remote 

temperature or the total pressure readings, or both, to the 

actual temperature or total pressure at the flow meter, or 

both, on a daily basis. You shall then use the actual 

temperature and total pressure values to correct the 

measured flow rates to standard conditions.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 44 of 520

Draft – Deliberative – Do Not Cite, Quote, or Release

(E) You shall periodically check the correlation(s) 

between the remote and actual readings (at least once a 

year), and make any necessary adjustments to the 

mathematical relationship(s).

(4) Fuel billing meters are exempted from the 

calibration requirements of this section and from the GHG 

Monitoring Plan and recordkeeping provisions of paragraphs 

(g)(5)(i)(C), (g)(6), and (g)(7) of this section, provided 

that the fuel supplier and any unit combusting the fuel do 

not have any common owners and are not owned by 

subsidiaries or affiliates of the same company. Meters used 

exclusively to measure the flow rates of fuels that are 

used for unit startup are also exempted from the 

calibration requirements of this section.

(5) For a flow meter that has been previously 

calibrated in accordance with paragraph (i)(1) of this 

section, an additional calibration is not required by the 

date specified in paragraph (i)(1) of this section if, as 

of that date, the previous calibration is still active ( 

i.e., the device is not yet due for recalibration because 

the time interval between successive calibrations has not 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 45 of 520

Draft – Deliberative – Do Not Cite, Quote, or Release

elapsed). In this case, the deadline for the successive 

calibrations of the flow meter shall be set according to 

one of the following. You may use either the manufacturer's 

recommended calibration schedule or you may use the 

industry consensus calibration schedule.

(6) For units and processes that operate continuously 

with infrequent outages, it may not be possible to meet the 

April 1, 2010 deadline for the initial calibration of a 

flow meter or other measurement device without disrupting 

normal process operation. In such cases, the owner or 

operator may postpone the initial calibration until the 

next scheduled maintenance outage. The best available 

information from company records may be used in the 

interim. The subsequent required recalibrations of the flow 

meters may be similarly postponed. Such postponements shall 

be documented in the monitoring plan that is required under 

paragraph (g)(5) of this section.

(7) If the results of an initial calibration or a 

recalibration fail to meet the required accuracy 

specification, data from the flow meter shall be considered 

invalid, beginning with the hour of the failed calibration 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 46 of 520

Draft – Deliberative – Do Not Cite, Quote, or Release

and continuing until a successful calibration is completed. 

You shall follow the missing data provisions provided in 

the relevant missing data sections during the period of 

data invalidation.

(j) Measurement device installation (1) General. If an 

owner or operator required to report under subpart P, 

subpart X or subpart Y of this part has process equipment 

or units that operate continuously and it is not possible 

to install a required flow meter or other measurement 

device by April 1, 2010, (or by any later date in 2010 

approved by the Administrator as part of an extension of 

best available monitoring methods per paragraph (d) of this 

section) without process equipment or unit shutdown, or 

through a hot tap, the owner or operator may request an 

extension from the Administrator to delay installing the 

measurement device until the next scheduled process 

equipment or unit shutdown. If approval for such an 

extension is granted by the Administrator, the owner or 

operator must use best available monitoring methods during 

the extension period.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 47 of 520

Draft – Deliberative – Do Not Cite, Quote, or Release

(2) Requests for extension of the use of best 

available monitoring methods for measurement device 

installation. The owner or operator must first provide the 

Administrator an initial notification of the intent to 

submit an extension request for use of best available 

monitoring methods beyond December 31, 2010 (or an earlier 

date approved by EPA) in cases where measurement device 

installation would require a process equipment or unit 

shutdown, or could only be done through a hot tap. The 

owner or operator must follow-up this initial notification 

with the complete extension request containing the 

information specified in paragraph (j)(4) of this section.

(3) Timing of request. (i) The initial notice of 

intent must be submitted no later than January 1, 2011, or 

by the end of the approved use of best available monitoring 

methods extension in 2010, whichever is earlier. The 

completed extension request must be submitted to the 

Administrator no later than February 15, 2011.

(ii) Any subsequent extensions to the original request 

must be submitted to the Administrator within 4 weeks of 

the owner or operator identifying the need to extend the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 48 of 520

Draft – Deliberative – Do Not Cite, Quote, or Release

request, but in any event no later than 4 weeks before the 

date for the planned process equipment or unit shutdown 

that was provided in the original request.

(4) Content of the request. Requests must contain the 

following information:

(i) Specific measurement device for which the request 

is being made and the location where each measurement 

device will be installed.

(ii) Identification of the specific rule requirements 

(by rule subpart, section, and paragraph numbers) requiring 

the measurement device.

(iii) A description of the reasons why the needed 

equipment could not be installed before April 1, 2010, or 

by the expiration date for the use of best available 

monitoring methods, in cases where an extension has been 

granted under §98.3(d).

(iv) Supporting documentation showing that it is not 

practicable to isolate the process equipment or unit and 

install the measurement device without a full shutdown or a 

hot tap, and that there was no opportunity during 2010 to 

install the device. Include the date of the three most 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 49 of 520

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recent shutdowns for each relevant process equipment or 

unit, the frequency of shutdowns for each relevant process 

equipment or unit, and the date of the next planned process 

equipment or unit shutdown.

(v) Include a description of the proposed best 

available monitoring method for estimating GHG emissions 

during the time prior to installation of the meter.

(5) Approval criteria. The owner or operator must 

demonstrate to the Administrator's satisfaction that it is 

not reasonably feasible to install the measurement device 

before April 1, 2010 (or by the expiration date for the use 

of best available monitoring methods, in cases where an 

extension has been granted under paragraph (d) of this 

section) without a process equipment or unit shutdown, or 

through a hot tap, and that the proposed method for 

estimating GHG emissions during the time before which the 

measurement device will be installed is appropriate. The 

Administrator will not initially approve the use of the 

proposed best available monitoring method past December 31, 

2013.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 50 of 520

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(6) Measurement device installation deadline. Any 

owner or operator that submits both a timely initial notice 

of intent and a timely completed extension request under 

paragraph (j)(3) of this section to extend use of best 

available monitoring methods for measurement device 

installation must install all such devices by July 1, 2011 

unless the extension request under this paragraph (j) is 

approved by the Administrator before July 1, 2011.

(7) One time extension past December 31, 2013. If an 

owner or operator determines that a scheduled process 

equipment or unit shutdown will not occur by December 31, 

2013, the owner or operator may re-apply to use best 

available monitoring methods for one additional time 

period, not to extend beyond December 31, 2015. To extend 

use of best available monitoring methods past December 31, 

2013, the owner or operator must submit a new extension 

request by June 1, 2013 that contains the information 

required in paragraph (j)(4) of this section. The owner or 

operator must demonstrate to the Administrator's 

satisfaction that it continues to not be reasonably 

feasible to install the measurement device before December 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 51 of 520

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31, 2013 without a process equipment or unit shutdown, or 

that installation of the measurement device could only be 

done through a hot tap, and that the proposed method for 

estimating GHG emissions during the time before which the 

measurement device will be installed is appropriate. An 

owner or operator that submits a request under this 

paragraph to extend use of best available monitoring 

methods for measurement device installation must install 

all such devices by December 31, 2013, unless the extension 

request under this paragraph is approved by the 

Administrator.

§98.4 Authorization and responsibilities of the designated 

representative.

(a) General. Except as provided under paragraph (f) of 

this section, each facility, and each supplier, that is 

subject to this part, shall have one and only one 

designated representative, who shall be responsible for 

certifying, signing, and submitting GHG emissions reports 

and any other submissions for such facility and supplier

respectively to the Administrator under this part. If the 

facility is required under any other part of title 40 of 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 52 of 520

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the Code of Federal Regulations to submit to the 

Administrator any other emission report that is subject to 

any requirement in 40 CFR part 75, the same individual 

shall be the designated representative responsible for 

certifying, signing, and submitting the GHG emissions 

reports and all such other emissions reports under this 

part. 

(b) Authorization of a designated representative. The 

designated representative of the facility or supplier shall 

be an individual selected by an agreement binding on the 

owners and operators of such facility or supplier and shall 

act in accordance with the certification statement in 

paragraph (i)(4)(iv) of this section. 

(c) Responsibility of the designated representative. 

Upon receipt by the Administrator of a complete certificate 

of representation under this section for a facility or 

supplier, the designated representative identified in such 

certificate of representation shall represent and, by his 

or her representations, actions, inactions, or submissions, 

legally bind each owner and operator of such facility or 

supplier in all matters pertaining to this part, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 53 of 520

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notwithstanding any agreement between the designated 

representative and such owners and operators. The owners 

and operators shall be bound by any decision or order 

issued to the designated representative by the 

Administrator or a court.

(d) Timing. No GHG emissions report or other 

submissions under this part for a facility or supplier will 

be accepted until the Administrator has received a complete 

certificate of representation under this section for a 

designated representative of the facility or supplier. Such 

certificate of representation shall be submitted at least

60 days before the deadline for submission of the 

facility’s or supplier’s initial emission report under this 

part.

(e) Certification of the GHG emissions report. Each 

GHG emission report and any other submission under this 

part for a facility or supplier shall be certified, signed, 

and submitted by the designated representative or any 

alternate designated representative of the facility or 

supplier in accordance with this section and §3.10 of this 

chapter.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 54 of 520

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(1) Each such submission shall include the following 

certification statement signed by the designated 

representative or any alternate designated representative: 

“I am authorized to make this submission on behalf of the 

owners and operators of the facility or supplier, as 

applicable, for which the submission is made. I certify 

under penalty of law that I have personally examined, and 

am familiar with, the statements and information submitted 

in this document and all its attachments. Based on my 

inquiry of those individuals with primary responsibility 

for obtaining the information, I certify that the 

statements and information are to the best of my knowledge 

and belief true, accurate, and complete. I am aware that 

there are significant penalties for submitting false 

statements and information or omitting required statements 

and information, including the possibility of fine or 

imprisonment.”

(2) The Administrator will accept a GHG emission 

report or other submission for a facility or supplier under 

this part only if the submission is certified, signed, and 

submitted in accordance with this section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Page 55 of 520

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(f) Alternate designated representative. A certificate 

of representation under this section for a facility or 

supplier may designate one alternate designated 

representative, who shall be an individual selected by an 

agreement binding on the owners and operators, and may act 

on behalf of the designated representative, of such 

facility or supplier. The agreement by which the alternate 

designated representative is selected shall include a 

procedure for authorizing the alternate designated 

representative to act in lieu of the designated 

representative.

(1) Upon receipt by the Administrator of a complete 

certificate of representation under this section for a 

facility or supplier identifying an alternate designated 

representative.

(i) The alternate designated representative may act on 

behalf of the designated representative for such facility 

or supplier.

(ii) Any representation, action, inaction, or 

submission by the alternate designated representative shall 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 56 of 520

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be deemed to be a representation, action, inaction, or 

submission by the designated representative.

(2) Except in this section, whenever the term 

“designated representative” is used in this part, the term 

shall be construed to include the designated representative 

or any alternate designated representative.

(g) Changing a designated representative or alternate 

designated representative. The designated representative or 

alternate designated representative identified in a 

complete certificate of representation under this section 

for a facility or supplier received by the Administrator 

may be changed at any time upon receipt by the 

Administrator of another later signed, complete certificate 

of representation under this section for the facility or 

supplier. Notwithstanding any such change, all 

representations, actions, inactions, and submissions by the 

previous designated representative or the previous 

alternate designated representative of the facility or 

supplier before the time and date when the Administrator 

receives such later signed certificate of representation 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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shall be binding on the new designated representative and 

the owners and operators of the facility or supplier.

(h) Changes in owners and operators. In the event an 

owner or operator of the facility or supplier is not 

included in the list of owners and operators in the 

certificate of representation under this section for the 

facility or supplier, such owner or operator shall be 

deemed to be subject to and bound by the certificate of 

representation, the representations, actions, inactions, 

and submissions of the designated representative and any 

alternate designated representative of the facility or 

supplier, as if the owner or operator were included in such 

list. Within 90 days after any change in the owners and 

operators of the facility or supplier (including the 

addition of a new owner or operator), the designated 

representative or any alternate designated representative 

shall submit a certificate of representation that is 

complete under this section except that such list shall be 

amended to reflect the change. If the designated 

representative or alternate designated representative 

determines at any time that an owner or operator of the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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facility or supplier is not included in such list and such 

exclusion is not the result of a change in the owners and 

operators, the designated representative or any alternate 

designated representative shall submit, within 90 days of 

making such determination, a certificate of representation 

that is complete under this section except that such list 

shall be amended to include such owner or operator. 

(i) Certificate of representation. A certificate of 

representation shall be complete if it includes the 

following elements in a format prescribed by the 

Administrator in accordance with this section:

(1) Identification of the facility or supplier for 

which the certificate of representation is submitted.

(2) The name, organization name (company affiliationemployer), address, e-mail address (if any), telephone 

number, and facsimile transmission number (if any) of the 

designated representative and any alternate designated 

representative.

(3) A list of the owners and operators of the facility 

or supplier identified in paragraph (i)(1) of this section, 

provided that, if the list includes the operators of the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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facility or supplier and the owners with control of the 

facility or supplier, the failure to include any other 

owners shall not make the certificate of representation 

incomplete.

(4) The following certification statements by the 

designated representative and any alternate designated 

representative:

(i) “I certify that I was selected as the designated 

representative or alternate designated representative, as 

applicable, by an agreement binding on the owners and 

operators of the facility or supplier, as applicable.”

(ii) “I certify that I have all the necessary 

authority to carry out my duties and responsibilities under 

40 CFR part 98 on behalf of the owners and operators of the 

facility or supplier, as applicable, and that each such 

owner and operator shall be fully bound by my 

representations, actions, inactions, or submissions.”

(iii) “I certify that the owners and operators of the 

facility or supplier, as applicable, shall be bound by any 

order issued to me by the Administrator or a court 

regarding the facility or supplier.”
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(iv) “If there are multiple owners and operators of 

the facility or supplier, as applicable, I certify that I 

have given a written notice of my selection as the 

‘designated representative’ or ‘alternate designated 

representative’, as applicable, and of the agreement by 

which I was selected to each owner and operator of the 

facility or supplier."

(5) The signature of the designated representative and 

any alternate designated representative and the dates 

signed.

(j) Documents of agreement. Unless otherwise required 

by the Administrator, documents of agreement referred to in 

the certificate of representation shall not be submitted to 

the Administrator. The Administrator shall not be under any 

obligation to review or evaluate the sufficiency of such 

documents, if submitted.

(k) Binding nature of the certificate of 

representation. Once a complete certificate of 

representation under this section for a facility or 

supplier has been received, the Administrator will rely on 

the certificate of representation unless and until a later 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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signed, complete certificate of representation under this 

section for the facility or supplier is received by the 

Administrator.

(l) Objections Concerning a Designated Representative

(1) Except as provided in paragraph (g) of this 

section, no objection or other communication submitted to 

the Administrator concerning the authorization, or any 

representation, action, inaction, or submission, of the 

designated representative or alternate designated 

representative shall affect any representation, action, 

inaction, or submission of the designated representative or 

alternate designated representative, or the finality of any 

decision or order by the Administrator under this part.

(2) The Administrator will not adjudicate any private 

legal dispute concerning the authorization or any 

representation, action, inaction, or submission of any 

designated representative or alternate designated 

representative.

(m) Delegation by designated representative and 

alternate designated representative.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(1) A designated representative or an alternate 

designated representative may delegate his or her own 

authority, to one or more individuals, to submit an 

electronic submission to the Administrator provided for or 

required under this part, except for a submission under 

this paragraph.

(2) In order to delegate his or her own authority, to 

one or more individuals, to submit an electronic submission 

to the Administrator in accordance with paragraph (m) (1) 

of this section, the designated representative or alternate 

designated representative must submit electronically to the 

Administrator a notice of delegation, in a format 

prescribed by the Administrator, that includes the 

following elements:

(i) The name, organization name (company affiliationemployer) address, e-mail address (if any), telephone 

number, and facsimile transmission number (if any) of such 

designated representative or alternate designated 

representative.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(ii) The name, address, e-mail address, telephone 

number, and facsimile transmission number (if any) of each 

such individual (referred to as an “agent”).

(iii) For each such individual, a list of the type or 

types of electronic submissions under paragraph (m)(1) of 

this section for which authority is delegated to him or 

her.

(iv) For each type of electronic submission listed in 

accordance with paragraph (m)(2)(iii) of this section, the 

facility or supplier for which the electronic submission 

may be made.

(v) The following certification statements by such 

designated representative or alternate designated 

representative:

(A) “I agree that any electronic submission to the 

Administrator that is by an agent identified in this notice 

of delegation and of a type listed, and for a facility or 

supplier designated, for such agent in this notice of 

delegation and that is made when I am a designated 

representative or alternate designated representative, as 

applicable, and before this notice of delegation is 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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superseded by another notice of delegation under 

§98.4(m)(3) shall be deemed to be an electronic submission 

certified, signed, and submitted by me.”

(B) “Until this notice of delegation is superseded by 

a later signed notice of delegation under §98.4(m)(3), I 

agree to maintain an e-mail account and to notify the 

Administrator immediately of any change in my e-mail 

address unless all delegation of authority by me under 

§98.4(m) is terminated.”.

(vi) The signature of such designated representative 

or alternate designated representative and the date signed. 

(3) A notice of delegation submitted in accordance 

with paragraph (m)(2) of this section shall be effective, 

with regard to the designated representative or alternate 

designated representative identified in such notice, upon 

receipt of such notice by the Administrator and until 

receipt by the Administrator of another such notice that 

was signed later by such designated representative or 

alternate designated representative, as applicable. The 

later signed notice of delegation may replace any 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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previously identified agent, add a new agent, or eliminate 

entirely any delegation of authority.

(4) Any electronic submission covered by the 

certification in paragraph (m)(2)(v)(A) of this section and 

made in accordance with a notice of delegation effective 

under paragraph (m)(3) of this section shall be deemed to 

be an electronic submission certified, signed, and 

submitted by the designated representative or alternate 

designated representative submitting such notice of 

delegation.

§98.5 How is the report submitted?

Each GHG report and certificate of representation for 

a facility or supplier must be submitted electronically in 

accordance with the requirements of §98.4 and in a format 

specified by the Administrator. 

§98.6 Definitions.

All terms used in this part shall have the same 

meaning given in the Clean Air Act and in this section. 

Absorbent circulation pump means a pump commonly 

powered by natural gas pressure that circulates the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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absorbent liquid between the absorbent regenerator and 

natural gas contactor.

Accuracy of a measurement at a specified level (e.g., 

one percent of full scale or one percent of the value 

measured) means that the mean of repeat measurements made 

by a device or technique are within 95 percent of the range 

bounded by the true value plus or minus the specified 

level.

Acid Rain Program means the program established under 

title IV of the Clean Air Act, and implemented under parts 

72 through 78 of this chapter for the reduction of sulfur 

dioxide and nitrogen oxides emissions.

Administrator means the Administrator of the United 

States Environmental Protection Agency or the 

Administrator’s authorized representative.

AGA means the American Gas Association

Agricultural by-products means those parts of arable 

crops that are not used for the primary purpose of 

producing food. Agricultural by-products include, but are 

not limited to, oat, corn and wheat straws, bagasse, peanut 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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shells, rice and coconut husks, soybean hulls, palm kernel 

cake, cottonseed and sunflower seed cake, and pomace.

Air injected flare means a flare in which air is blown 

into the base of a flare stack to induce complete 

combustion of gas.

Alkali bypass means a duct between the feed end of the 

kiln and the preheater tower through which a portion of the 

kiln exit gas stream is withdrawn and quickly cooled by air 

or water to avoid excessive buildup of alkali, chloride 

and/or sulfur on the raw feed. This may also be referred to 

as the “kiln exhaust gas bypass.”

Anaerobic digester means the system where wastes are 

collected and anaerobically digested in large containment 

vessels or covered lagoons. Anaerobic digesters stabilize 

waste by the microbial reduction of complex organic 

compounds to CO2 and CH4, which is captured and may be 

flared or used as fuel. Anaerobic digestion systems, 

include but are not limited to covered lagoon, complete 

mix, plug flow, and fixed film digesters.

Anaerobic lagoon, with respect to subpart JJ of this 

part, means a type of liquid storage system component that 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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is designed and operated to stabilize wastes using 

anaerobic microbial processes. Anaerobic lagoons may be 

designed for combined stabilization and storage with 

varying lengths of retention time (up to a year or 

greater), depending on the climate region, volatile solids 

loading rate, and other operational factors.

Anode effect is a process upset condition of an 

aluminum electrolysis cell caused by too little alumina 

dissolved in the electrolyte. The anode effect begins when 

the voltage rises rapidly and exceeds a threshold voltage, 

typically 8 volts. 

Anode Effect Minutes per Cell Day (24 hours) are the 

total minutes during which an electrolysis cell voltage is 

above the threshold voltage, typically 8 volts.

ANSI means the American National Standards Institute.

API means the American Petroleum Institute.

ASABE means the American Society of Agricultural and 

Biological Engineers.

ASME means the American Society of Mechanical 

Engineers.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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ASTM means the American Society of Testing and 

Materials.

Asphalt means a dark brown-to-black cement-like 

material obtained by petroleum processing and containing 

bitumens as the predominant component. It includes crude 

asphalt as well as the following finished products: 

cements, fluxes, the asphalt content of emulsions 

(exclusive of water), and petroleum distillates blended 

with asphalt to make cutback asphalts. 

Aviation Gasoline means a complex mixture of volatile 

hydrocarbons, with or without additives, suitably blended 

to be used in aviation reciprocating engines. 

Specifications can be found in ASTM Specification D910–07a, 

Standard Specification for Aviation Gasolines (incorporated 

by reference, see §98.7).

B0 means the maximum CH4 producing capacity of a waste 

stream, kg CH4/kg COD.

Basic oxygen furnace means any refractory-lined vessel 

in which high-purity oxygen is blown under pressure through 

a bath of molten iron, scrap metal, and fluxes to produce 

steel. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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bbl means barrel.

Biodiesel means a mono-akyl ester derived from biomass 

and conforming to ASTM D6751-08, Standard Specification for 

Biodiesel Fuel Blend Stock (B100) for Middle Distillate 

Fuels.

Biogenic CO2 means carbon dioxide emissions generated 

as the result of biomass combustion from combustion units 

for which emission calculations are required by an 

applicable part 98 subpart. 

Biomass means non-fossilized and biodegradable organic 

material originating from plants, animals or microorganisms, including products, by-products, residues and 

waste from agriculture, forestry and related industries as 

well as the non-fossilized and biodegradable organic 

fractions of industrial and municipal wastes, including 

gases and liquids recovered from the decomposition of nonfossilized and biodegradable organic material. 

Blast furnace means a furnace that is located at an 

integrated iron and steel plant and is used for the 

production of molten iron from iron ore pellets and other 

iron bearing materials.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Blendstocks are petroleum products used for blending 

or compounding into finished motor gasoline. These include 

RBOB (reformulated blendstock for oxygenate blending) and 

CBOB (conventional blendstock for oxygenate blending), but 

exclude oxygenates, butane, and pentanes plus.

Blendstocks -- Others are products used for blending 

or compounding into finished motor gasoline that are not 

defined elsewhere. Excludes Gasoline Treated as Blendstock 

(GTAB), Diesel Treated as Blendstock (DTAB), conventional 

blendstock for oxygenate blending (CBOB), reformulated 

blendstock for oxygenate blending (RBOB), oxygenates (e.g. 

fuel ethanol and methyl tertiary butyl ether), butane, and 

pentanes plus. 

Blowdown mean the act of emptying or depressuring a 

vessel. This may also refer to the discarded material such 

as blowdown water from a boiler or cooling tower.

Blowdown vent stack emissions mean natural gas and/or 

CO2 released due to maintenance and/or blowdown operations 

including compressor blowdown and emergency shut-down (ESD) 

system testing. Emissions from emergency events are not 

included. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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British Thermal Unit or Btu means the quantity of heat 

required to raise the temperature of one pound of water by 

one degree Fahrenheit at about 39.2 degrees Fahrenheit.

Bulk, with respect to industrial GHG suppliers and CO2 

suppliers, means the transfer of a product inside 

containers, including but not limited to tanks, cylinders, 

drums, and pressure vessels.

Bulk natural gas liquid or NGL refers to mixtures of 

hydrocarbons that have been separated from natural gas as 

liquids through the process of absorption, condensation, 

adsorption, or other methods. Generally, such liquids 

consist of ethane, propane, butanes, and pentanes plus. 

Bulk NGL is sold to fractionators or to refineries and 

petrochemical plants where the fractionation takes place.

Butane, or n-Butane, is a paraffinic straight-chain 

hydrocarbon with molecular formula C4H10.

Butylene, or n-Butylene, is an olefinic straight-chain 

hydrocarbon with molecular formula C4H8.

By-product coke oven battery means a group of ovens 

connected by common walls, where coal undergoes destructive 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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distillation under positive pressure to produce coke and 

coke oven gas from which by-products are recovered.

Calcination means the process of thermally treating 

minerals to decompose carbonates from ore.

Calculation methodology means a methodology prescribed 

under the section “Calculating GHG Emissions” in any 

subpart of part 98.

Calibrated bag means a flexible, non-elastic, antistatic bag of a calibrated volume that can be affixed to an 

emitting source such that the emissions inflate the bag to 

its calibrated volume.

Carbon dioxide equivalent or CO2e means the number of 

metric tons of CO2 emissions with the same global warming 

potential as one metric ton of another greenhouse gas, and 

is calculated using Equation A-1 of this subpart.

Carbon dioxide production well means any hole drilled 

in the earth for the primary purpose of extracting carbon 

dioxide from a geologic formation or group of formations 

which contain deposits of carbon dioxide.

Carbon dioxide production well facility means one or 

more carbon dioxide production wells that are located on 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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one or more contiguous or adjacent properties, which are 

under the control of the same entity. Carbon dioxide 

production wells located on different oil and gas leases, 

mineral fee tracts, lease tracts, subsurface or surface 

unit areas, surface fee tracts, surface lease tracts, or 

separate surface sites, whether or not connected by a road, 

waterway, power line, or pipeline, shall be considered part 

of the same CO2 production well facility if they otherwise 

meet the definition.

Carbon dioxide stream means carbon dioxide that has 

been captured from an emission source (e.g. a power plant 

or other industrial facility) or extracted from a carbon 

dioxide production well plus incidental associated 

substances either derived from the source materials and the 

capture process or extracted with the carbon dioxide.

Carbon share means the percent of total mass that 

carbon represents in any product.

Carbonate means compounds containing the radical CO3

-2. 

Upon calcination, the carbonate radical decomposes to 

evolve carbon dioxide (CO2). Common carbonates consumed in 

the mineral industry include calcium carbonate (CaCO3) or 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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calcite; magnesium carbonate (MgCO3) or magnesite; and 

calcium-magnesium carbonate (CaMg(CO3)2) or dolomite.

Carbonate-based mineral means any of the following 

minerals used in the manufacture of glass: Calcium 

carbonate (CaCO3), calcium magnesium carbonate (CaMg(CO3)2), 

sodium carbonate (Na2CO3), barium carbonate (BaCO3), 

potassium carbonate (K2CO3), lithium carbonate (Li2CO3), and 

strontium carbonate (SrCO3). 

Carbonate-based mineral mass fraction means the 

following: For limestone, the mass fraction of calcium 

carbonate (CaCO3) in the limestone; for dolomite, the mass 

fraction of calcium magnesium carbonate (CaMg(CO3)2) in the 

dolomite; for soda ash, the mass fraction of sodium 

carbonate (Na2CO3) in the soda ash; for barium carbonate, 

the mass fraction of barium carbonate (BaCO3) in the barium 

carbonate; for potassium carbonate, the mass fraction of 

potassium carbonate (K2CO3) in the potassium carbonate; for 

lithium carbonate, the mass fraction of lithium carbonate 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(Li2CO3); and for strontium carbonate, the mass fraction of 

strontium carbonate (SrCO3).

Carbonate-based raw material means any of the 

following materials used in the manufacture of glass: 

limestone, dolomite, soda ash, barium carbonate, potassium 

carbonate, lithium carbonate, and strontium carbonate.

Catalytic cracking unit means a refinery process unit 

in which petroleum derivatives are continuously charged and 

hydrocarbon molecules in the presence of a catalyst are 

fractured into smaller molecules, or react with a contact 

material suspended in a fluidized bed to improve feedstock 

quality for additional processing and the catalyst or 

contact material is continuously regenerated by burning off 

coke and other deposits. Catalytic cracking units include 

both fluidized bed systems, which are referred to as fluid 

catalytic cracking units (FCCU), and moving bed systems, 

which are also referred to as thermal catalytic cracking 

units. The unit includes the riser, reactor, regenerator, 

air blowers, spent catalyst or contact material stripper, 

catalyst or contact material recovery equipment, and 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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regenerator equipment for controlling air pollutant 

emissions and for heat recovery.

CBOB-Summer (conventional blendstock for oxygenate 

blending) means a petroleum product which, when blended 

with a specified type and percentage of oxygenate, meets 

the definition of Conventional-Summer.

CBOB-Winter (conventional blendstock for oxygenate 

blending) means a petroleum product which, when blended 

with a specified type and percentage of oxygenate, meets 

the definition of Conventional-Winter.

Cement kiln dust means non-calcined to fully calcined 

dust produced in the kiln or pyroprocessing line. Cement 

kiln dust is a fine-grained, solid, highly alkaline 

material removed from the cement kiln exhaust gas by 

scrubbers (filtration baghouses and/or electrostatic 

precipitators).

Centrifugal compressor means any equipment that 

increases the pressure of a process natural gas or CO2 by 

centrifugal action, employing rotating movement of the 

driven shaft.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Centrifugal compressor dry seals mean a series of 

rings around the compressor shaft where it exits the 

compressor case that operates mechanically under the 

opposing forces to prevent natural gas or CO2 from escaping 

to the atmosphere.

Centrifugal compressor dry seal emissions mean natural 

gas or CO2 released from a dry seal vent pipe and/or the 

seal face around the rotating shaft where it exits one or 

both ends of the compressor case.

Centrifugal compressor wet seal degassing vent 

emissions means emissions that occur when the high-pressure 

oil barriers for centrifugal compressors are depressurized 

to release absorbed natural gas or CO2. High-pressure oil is 

used as a barrier against escaping gas in centrifugal 

compressor shafts. Very little gas escapes through the oil 

barrier, but under high pressure, considerably more gas is 

absorbed by the oil. The seal oil is purged of the absorbed 

gas (using heaters, flash tanks, and degassing techniques) 

and recirculated. The separated gas is commonly vented to 

the atmosphere. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Certified standards means calibration gases certified 

by the manufacturer of the calibration gases to be accurate 

to within 2 percent of the value on the label or 

calibration gases.

CH4 means methane.

Chemical recovery combustion unit means a combustion 

device, such as a recovery furnace or fluidized-bed reactor 

where spent pulping liquor from sulfite or semi-chemical 

pulping processes is burned to recover pulping chemicals.

Chemical recovery furnace means an enclosed combustion 

device where concentrated spent liquor produced by the 

kraft or soda pulping process is burned to recover pulping 

chemicals and produce steam. Includes any recovery furnace 

that burns spent pulping liquor produced from both the 

kraft and soda pulping processes.

Chloride process means a production process where 

titanium dioxide is produced using calcined petroleum coke 

and chlorine as raw materials.

City gate means a location at which natural gas 

ownership or control passes from one party to another, 

neither of which is the ultimate consumer. In this rule, in 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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keeping with common practice, the term refers to a point or 

measuring station at which a local gas distribution utility 

receives gas from a natural gas pipeline company or 

transmission system. Meters at the city gate station 

measure the flow of natural gas into the local distribution 

company system and typically are used to measure local 

distribution company system sendout to customers. 

CO2 means carbon dioxide.

Coal means all solid fuels classified as anthracite, 

bituminous, sub-bituminous, or lignite by the American 

Society for Testing and Materials Designation ASTM D388–05 

Standard Classification of Coals by Rank (incorporated by 

reference, see §98.7).

COD means the chemical oxygen demand as determined 

using methods specified pursuant to 40 CFR part 136.

Cogeneration unit means a unit that produces 

electrical energy and useful thermal energy for 

industrial, commercial, or heating or cooling purposes, 

through the sequential or simultaneous use of the original 

fuel energy.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Coke burn-off means the coke removed from the surface 

of a catalyst by combustion during catalyst regeneration. 

Coke burn-off also means the coke combusted in fluid coking 

unit burner.

Cokemaking means the production of coke from coal in 

either a by-product coke oven battery or a non-recovery 

coke oven battery.

Commercial applications means executing a commercial 

transaction subject to a contract. A commercial application 

includes transferring custody of a product from one 

facility to another if it otherwise meets the definition.

Company records means, in reference to the amount of 

fuel consumed by a stationary combustion unit (or by a 

group of such units), a complete record of the methods

used, the measurements made, and the calculations performed 

to quantify fuel usage. Company records may include, but 

are not limited to, direct measurements of fuel consumption 

by gravimetric or volumetric means, tank drop measurements, 

and calculated values of fuel usage obtained by measuring 

auxiliary parameters such as steam generation or unit 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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operating hours. Fuel billing records obtained from the 

fuel supplier qualify as company records. 

Connector means to flanged, screwed, or other joined 

fittings used to connect pipe line segments, tubing, pipe 

components (such as elbows, reducers, “T’s” or valves) or a 

pipe line and a piece of equipment or an instrument to a 

pipe, tube or piece of equipment. A common connector is a 

flange. Joined fittings welded completely around the 

circumference of the interface are not considered 

connectors for the purpose of this part.

Container glass means glass made of soda-lime recipe, 

clear or colored, which is pressed and/or blown into 

bottles, jars, ampoules, and other products listed in North 

American Industry Classification System 327213 (NAICS 

327213).

Continuous bleed means a continuous flow of pneumatic 

supply gas to the process measurement device (e.g. level 

control, temperature control, pressure control) where the 

supply gas pressure is modulated by the process condition, 

and then flows to the valve controller where the signal is 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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compared with the process set-point to adjust gas pressure 

in the valve actuator.

Continuous emission monitoring system or CEMS means 

the total equipment required to sample, analyze, measure, 

and provide, by means of readings recorded at least once 

every 15 minutes, a permanent record of gas concentrations, 

pollutant emission rates, or gas volumetric flow rates from 

stationary sources.

Continuous glass melting furnace means a glass melting 

furnace that operates continuously except during periods of 

maintenance, malfunction, control device installation, 

reconstruction, or rebuilding.

Conventional—Summer refers to finished gasoline 

formulated for use in motor vehicles, the composition and 

properties of which do not meet the requirements of the 

reformulated gasoline regulations promulgated by the U.S. 

Environmental Protection Agency under 40 CFR 80.40, but 

which meet summer RVP standards required under 40 CFR 80.27 

or as specified by the state. Note: This category excludes 

conventional gasoline for oxygenate blending (CBOB) as well 

as other blendstock.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Conventional—Winter refers to finished gasoline 

formulated for use in motor vehicles, the composition and 

properties of which do not meet the requirements of the 

reformulated gasoline regulations promulgated by the U.S. 

Environmental Protection Agency under 40 CFR 80.40 or the 

summer RVP standards required under 40 CFR 80.27 or as 

specified by the state. Note: This category excludes 

conventional blendstock for oxygenate blending (CBOB) as 

well as other blendstock.

Crude oil means a mixture of hydrocarbons that exists 

in liquid phase in natural underground reservoirs and 

remains liquid at atmospheric pressure after passing 

through surface separating facilities. (1) Depending upon 

the characteristics of the crude stream, it may also 

include any of the following: 

(i) Small amounts of hydrocarbons that exist in 

gaseous phase in natural underground reservoirs but are 

liquid at atmospheric conditions (temperature and pressure) 

after being recovered from oil well (casing-head) gas in 

lease separators and are subsequently commingled with the 

crude stream without being separately measured. Lease 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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condensate recovered as a liquid from natural gas wells in 

lease or field separation facilities and later mixed into 

the crude stream is also included. 

(ii) Small amounts of non-hydrocarbons, such as sulfur 

and various metals. 

(iii) Drip gases, and liquid hydrocarbons produced 

from tar sands, oil sands, gilsonite, and oil shale. 

(iv) Petroleum products that are received or produced 

at a refinery and subsequently injected into a crude supply 

or reservoir by the same refinery owner or operator. 

(2) Liquids produced at natural gas processing plants 

are excluded. Crude oil is refined to produce a wide array 

of petroleum products, including heating oils; gasoline, 

diesel and jet fuels; lubricants; asphalt; ethane, propane, 

and butane; and many other products used for their energy 

or chemical content.

Daily spread means a manure management system 

component in which manure is routinely removed from a 

confinement facility and is applied to cropland or pasture 

within 24 hours of excretion.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Day means any consistently designated 24 hour period 

during which an emission unit is operated.

Decarburization vessel means any vessel used to 

further refine molten steel with the primary intent of 

reducing the carbon content of the steel, including but not 

limited to vessels used for argon-oxygen decarburization 

and vacuum oxygen decarburization.

Deep bedding systems for cattle swine means a manure 

management system in which, as manure accumulates, bedding 

is continually added to absorb moisture over a production 

cycle and possibly for as long as 6 to 12 months. This 

manure management system also is known as a bedded pack 

manure management system and may be combined with a dry lot 

or pasture.

Degasification system means the entirety of the 

equipment that is used to drain gas from underground and 

collect it at a common point, such as a vacuum pumping 

station. This includes all degasification wells and gob gas 

vent holes at the underground coal mine. Degasification 

systems include pre-mining, horizontal pre-mining, and 

post-mining systems.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Degradable organic carbon (DOC) means the fraction of 

the total mass of a waste material that can be biologically 

degraded.

Dehydrator means a device in which a liquid absorbent 

(including desiccant, ethylene glycol, diethylene glycol, 

or triethylene glycol) directly contacts a natural gas 

stream to absorb water vapor. 

Dehydrator vent emissions means natural gas and CO2

released from a natural gas dehydrator system absorbent 

(typically glycol) reboiler or regenerator to the 

atmosphere or a flare, including stripping natural gas and 

motive natural gas used in absorbent circulation pumps.

Delayed coking unit means one or more refinery process 

units in which high molecular weight petroleum derivatives 

are thermally cracked and petroleum coke is produced in a 

series of closed, batch system reactors. A delayed coking

unit consists of the coke drums and ancillary equipment

associated with a single fractionator.

De-methanizer means the natural gas processing unit 

that separates methane rich residue gas from the heavier 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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hydrocarbons (e.g., ethane, propane, butane, pentane-plus) 

in feed natural gas stream.

Density means the mass contained in a given unit 

volume (mass/volume).

Desiccant means a material used in solid-bed 

dehydrators to remove water from raw natural gas by 

adsorption or absorption. Desiccants include activated 

alumina, pelletized calcium chloride, lithium chloride and 

granular silica gel material. Wet natural gas is passed 

through a bed of the granular or pelletized solid adsorbent 

or absorbent in these dehydrators. As the wet gas contacts 

the surface of the particles of desiccant material, water 

is adsorbed on the surface or absorbed and dissolves the 

surface of these desiccant particles. Passing through the 

entire desiccant bed, almost all of the water is adsorbed 

onto or absorbed into the desiccant material, leaving the 

dry gas to exit the contactor.

Destruction means:

(1) With respect to landfills and manure management, 

the combustion of methane in any on-site or off-site 

combustion technology. Destroyed methane includes, but is 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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not limited to, methane combusted by flaring, methane 

destroyed by thermal oxidation, methane combusted for use 

in on-site energy or heat production technologies, methane 

that is conveyed through pipelines (including natural gas 

pipelines) for off-site combustion, and methane that is 

collected for any other on-site or off-site use as a fuel.

(2) With respect to fluorinated GHGs, the expiration 

of a fluorinated GHG to the destruction efficiency actually 

achieved. Such destruction does not result in a 

commercially useful end product. 

Destruction device, for the purposes of subparts II 

and TT of this part, means a flare, thermal oxidizer, 

boiler, turbine, internal combustion engine, or any other 

combustion unit used to destroy or oxidize methane 

contained in landfill gas or wastewater biogas.

Destruction efficiency means the efficiency with which 

a destruction device reduces the mass of a greenhouse gas 

fed into the device. Destruction efficiency, or flaring 

destruction efficiency, refers to the fraction of the gas 

that leaves the flare partially or fully oxidized. The 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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destruction efficiency is expressed in Equation A-2 of this 

section:

iIN

iOUT

tGHG

tGHG DE  1 (Eq. A-2)

Where:

DE = Destruction Efficiency 

tGHGiIN = The mass of GHG i fed into the destruction 

device

tGHGiOUT = The mass of GHG i exhausted from the 

destruction device

Diesel–Other is any distillate fuel oil not defined 

elsewhere, including Diesel Treated as Blendstock (DTAB).

DIPE (diisopropyl ether, (CH3)2CHOCH(CH3)2) is an ether 

as described in "Oxygenates."

Direct liquefaction means the conversion of coal 

directly into liquids, rather than passing through an 

intermediate gaseous state.

Direct reduction furnace means a high temperature 

furnace typically fired with natural gas to produce solid 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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iron from iron ore or iron ore pellets and coke, coal, or 

other carbonaceous materials.

Distillate fuel oil means a classification for one of 

the petroleum fractions produced in conventional 

distillation operations and from crackers and hydrotreating 

process units. The generic term distillate fuel oil 

includes kerosene, kerosene-type jet fuel, diesel fuels 

(Diesel Fuels No. 1, No. 2, and No. 4), and fuel oils (Fuel 

Oils No. 1, No. 2, and No. 4).

Distillate Fuel No. 1 has a maximum distillation 

temperature of 550 °F at the 90 percent recovery point and 

a minimum flash point of 100 °F and includes fuels commonly 

known as Diesel Fuel No. 1 and Fuel Oil No. 1, but excludes 

kerosene. This fuel is further subdivided into categories 

of sulfur content: High Sulfur (greater than 500 ppm), Low 

Sulfur (less than or equal to 500 ppm and greater than 15 

ppm), and Ultra Low Sulfur (less than or equal to 15 ppm).

Distillate Fuel No. 2 has a minimum and maximum 

distillation temperature of 540 °F and 640 °F at the 90 

percent recovery point, respectively, and includes fuels 

commonly known as Diesel Fuel No. 2 and Fuel Oil No. 2. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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This fuel is further subdivided into categories of sulfur 

content: High Sulfur (greater than 500 ppm), Low Sulfur 

(less than or equal to 500 ppm and greater than 15 ppm), 

and Ultra Low Sulfur (less than or equal to 15 ppm).

Distillate Fuel No. 4 is a distillate fuel oil made by 

blending distillate fuel oil and residual fuel oil, with a 

minimum flash point of 131 °F.

DOCf means the fraction of DOC that actually 

decomposes under the (presumably anaerobic) conditions 

within the landfill. 

Dry lot means a manure management system component 

consisting of a paved or unpaved open confinement area 

without any significant vegetative cover where accumulating 

manure may be removed periodically.

Electric arc furnace (EAF) means a furnace that 

produces molten alloy metal and heats the charge materials 

with electric arcs from carbon electrodes.

Electric arc furnace steelmaking means the production 

of carbon, alloy, or specialty steels using an EAF. This 

definition excludes EAFs at steel foundries and EAFs used 

to produce nonferrous metals.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Electrothermic furnace means a furnace that heats the 

charged materials with electric arcs from carbon 

electrodes.

Emergency generator means a stationary combustion 

device, such as a reciprocating internal combustion engine 

or turbine that serves solely as a secondary source of 

mechanical or electrical power whenever the primary energy 

supply is disrupted or discontinued during power outages or 

natural disasters that are beyond the control of the owner 

or operator of a facility. An emergency generator operates

only during emergency situations, for training of personnel 

under simulated emergency conditions, as part of emergency 

demand response procedures, or for standard performance 

testing procedures as required by law or by the generator

manufacturer. A generator that serves as a back-up power 

source under conditions of load shedding, peak shaving, 

power interruptions pursuant to an interruptible power 

service agreement, or scheduled facility maintenance shall 

not be considered an emergency generator.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Emergency equipment means any auxiliary fossil fuelpowered equipment, such as a fire pump, that is used only 

in emergency situations.

ETBE (ethyl tertiary butyl ether, (CH3)3COC2H) is an 

ether as described in "Oxygenates."

Ethane is a paraffinic hydrocarbon with molecular 

formula C2H6. 

Ethanol is an anhydrous alcohol with molecular formula 

C2H5OH.

Ethylene is an olefinic hydrocarbon with molecular 

formula C2H4. 

Ex refinery gate means the point at which a petroleum 

product leaves the refinery.

Experimental furnace means a glass melting furnace 

with the sole purpose of operating to evaluate glass 

melting processes, technologies, or glass products. An 

experimental furnace does not produce glass that is sold 

(except for further research and development purposes) or 

that is used as a raw material for non-experimental 

furnaces.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Export means to transport a product from inside the 

United States to persons outside the United States, 

excluding any such transport on behalf of the United States 

military including foreign military sales under the Arms 

Export Control Act.

Exporter means any person, company or organization of 

record that transfers for sale or for other benefit, 

domestic products from the United States to another country 

or to an affiliate in another country, excluding any such 

transfers on behalf of the United States military or 

military purposes including foreign military sales under 

the Arms Export Control Act. An exporter is not the entity 

merely transporting the domestic products, rather an 

exporter is the entity deriving the principal benefit from 

the transaction. 

Facility means any physical property, plant, building, 

structure, source, or stationary equipment located on one 

or more contiguous or adjacent properties in actual 

physical contact or separated solely by a public roadway or 

other public right-of-way and under common ownership or 

common control, that emits or may emit any greenhouse gas. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Operators of military installations may classify such 

installations as more than a single facility based on 

distinct and independent functional groupings within 

contiguous military properties.

Feed means the prepared and mixed materials, which 

include but are not limited to materials such as limestone, 

clay, shale, sand, iron ore, mill scale, cement kiln dust 

and flyash, that are fed to the kiln. Feed does not include 

the fuels used in the kiln to produce heat to form the 

clinker product.

Feedstock means raw material inputs to a process that 

are transformed by reaction, oxidation, or other chemical 

or physical methods into products and by-products. 

Supplemental fuel burned to provide heat or thermal energy 

is not a feedstock.

Fischer-Tropsch process means a catalyzed chemical 

reaction in which synthesis gas, a mixture of carbon 

monoxide and hydrogen, is converted into liquid 

hydrocarbons of various forms.

Flare means a combustion device, whether at ground 

level or elevated, that uses an open flame to burn 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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combustible gases with combustion air provided by 

uncontrolled ambient air around the flame. 

Flat glass means glass made of soda-lime recipe and 

produced into continuous flat sheets and other products

listed in NAICS 327211.

Flowmeter means a device that measures the mass or 

volumetric rate of flow of a gas, liquid, or solid moving 

through an open or closed conduit (e.g. flowmeters include, 

but are not limited to, rotameters, turbine meters, 

coriolis meters, orifice meters, ultra-sonic flowmeters, 

and vortex flowmeters).

Fluid coking unit means one or more refinery process 

units in which high molecular weight petroleum derivatives 

are thermally cracked and petroleum coke is continuously 

produced in a fluidized bed system. The fluid coking unit 

includes equipment for controlling air pollutant emissions 

and for heat recovery on the fluid coking burner exhaust 

vent. There are two basic types of fluid coking units: A

traditional fluid coking unit in which only a small portion 

of the coke produced in the unit is burned to fuel the unit 

and the fluid coking burner exhaust vent is directed to the 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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atmosphere (after processing in a CO boiler or other air 

pollutant control equipment) and a flexicoking unit in 

which an auxiliary burner is used to partially combust a 

significant portion of the produced petroleum coke to 

generate a low value fuel gas that is used as fuel in other 

combustion sources at the refinery.

Fluorinated greenhouse gas means sulfur hexafluoride 

(SF6), nitrogen trifluoride (NF3), and any fluorocarbon 

except for controlled substances as defined at 40 CFR part 

82, subpart A and substances with vapor pressures of less 

than 1 mm of Hg absolute at 25 degrees C. With these 

exceptions, “fluorinated GHG” includes but is not limited 

to any hydrofluorocarbon, any perfluorocarbon, any fully 

fluorinated linear, branched or cyclic alkane, ether, 

tertiary amine or aminoether, any perfluoropolyether, and 

any hydrofluoropolyether. 

Fossil fuel means natural gas, petroleum, coal, or any 

form of solid, liquid, or gaseous fuel derived from such 

material, for purpose of creating useful heat.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 99 of 520

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Fossil fuel-fired means powered by combustion of 

fossil fuel, alone or in combination with any other fuel, 

regardless of the percentage of fossil fuel consumed.

Fractionators means plants that produce fractionated 

natural gas liquids (NGLs) extracted from produced natural 

gas and separate the NGLs individual component products: 

ethane, propane, butanes and pentane-plus (C5+). Plants 

that only process natural gas but do not fractionate NGLs 

further into component products are not considered 

fractionators. Some fractionators do not process production 

gas, but instead fractionate bulk NGLs received from 

natural gas processors. Some fractionators both process 

natural gas and fractionate bulk NGLs received from other 

plants.

Fuel means solid, liquid or gaseous combustible 

material.

Fuel gas means gas generated at a petroleum refinery 

or petrochemical plant and that is combusted separately or 

in any combination with any type of gas.

Fuel gas system means a system of compressors, piping, 

knock-out pots, mix drums, and, if necessary, units used to 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 100 of 520

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remove sulfur contaminants from the fuel gas (e.g., amine 

scrubbers) that collects fuel gas from one or more sources 

for treatment, as necessary, and transport to a stationary 

combustion unit. A fuel gas system may have an overpressure 

vent to a flare but the primary purpose for a fuel gas 

system is to provide fuel to the various combustion units 

at the refinery or petrochemical plant.

Furnace slag means a by-product formed in metal 

melting furnaces when slagging agents, reducing agents, 

and/or fluxes (e.g., coke ash, limestone, silicates) are 

added to remove impurities from the molten metal.

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 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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opening or pipe (vent) is installed to allow for natural 

gas flow.

Gas conditions mean the actual temperature, volume, 

and pressure of a gas sample. 

Gas-fired unit means a stationary combustion unit that 

derives more than 50 percent of its annual heat input from 

the combustion of gaseous fuels, and the remainder of its 

annual heat input from the combustion of fuel oil or other 

liquid fuels. 

Gas monitor means an instrument that continuously 

measures the concentration of a particular gaseous species 

in the effluent of a stationary source.

Gas to oil ratio (GOR) means the ratio of the volume 

of gas at standard temperature and pressure that is 

produced from a volume of oil when depressurized to 

standard temperature and pressure.

Gaseous fuel means a material that is in the gaseous 

state at standard atmospheric temperature and pressure 

conditions and that is combusted to produce heat and/or 

energy.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Gasification means the conversion of a solid or liquid 

raw material into a gas.

Gasoline – Other is any gasoline that is not defined 

elsewhere, including GTAB (gasoline treated as blendstock).

Glass melting furnace means a unit comprising a 

refractory-lined vessel in which raw materials are charged 

and melted at high temperature to produce molten glass.

Glass produced means the weight of glass exiting a 

glass melting furnace.

Global warming potential or GWP means the ratio of the 

time-integrated radiative forcing from the instantaneous 

release of one kilogram of a trace substance relative to 

that of one kilogram- of a reference gas, i.e., CO2. 

GPA means the Gas Processors Association.

Greenhouse gas or GHG means carbon dioxide (CO2), 

methane (CH4), nitrous oxide (N2O), sulfur hexafluoride 

(SF6), hydrofluorocarbons (HFCs), perfluorocarbons (PFCs), 

and other fluorinated greenhouse gases as defined in this 

section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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GTBA (gasoline-grade tertiary butyl alcohol, 

(CH3)3COH), or t-butanol, is an alcohol as described in 

"Oxygenates.”

Heavy Gas Oils are petroleum distillates with an 

approximate boiling range from 651 °F to 1,000 °F. 

Heel means the amount of gas that remains in a 

shipping container after it is discharged or off-loaded 

(that is no more than ten percent of the volume of the 

container).

High-bleed pneumatic devices are automated, continuous 

bleed flow control devices powered by pressurized natural 

gas and used for maintaining a process condition such as 

liquid level, pressure, delta-pressure and temperature. 

Part of the gas power stream that is regulated by the 

process condition flows to a valve actuator controller 

where it vents continuously (bleeds) to the atmosphere at a 

rate in excess of 6 standard cubic feet per hour.

High heat value or HHV means the high or gross heat 

content of the fuel with the heat of vaporization included. 

The water is assumed to be in a liquid state.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Hydrofluorocarbons or HFCs means a class of GHGs 

consisting of hydrogen, fluorine, and carbon.

Import means, to land on, bring into, or introduce 

into, any place subject to the jurisdiction of the United 

States whether or not such landing, bringing, or 

introduction constitutes an importation within the meaning 

of the customs laws of the United States, with the 

following exemptions:

(1) Off-loading used or excess fluorinated GHGs or 

nitrous oxide of U.S. origin from a ship during servicing.

(2) Bringing fluorinated GHGs or nitrous oxide into 

the U.S. from Mexico where the fluorinated GHGs or nitrous 

oxide had been admitted into Mexico in bond and were of 

U.S. origin.

(3) Bringing fluorinated GHGs or nitrous oxide into 

the U.S. when transported in a consignment of personal or 

household effects or in a similar non-commercial situation 

normally exempted from U.S. Customs attention. 

(4) Bringing fluorinated GHGs or nitrous into U.S. 

jurisdiction exclusively for U. S. military purposes.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Importer means any person, company, or organization of 

record that for any reason brings a product into the United 

States from a foreign country, excluding introduction into 

U.S. jurisdiction exclusively for United States military 

purposes. An importer is the person, company, or 

organization primarily liable for the payment of any duties 

on the merchandise or an authorized agent acting on their 

behalf. The term includes, as appropriate:

(1) The consignee.

(2) The importer of record.

(3) The actual owner.

(4) The transferee, if the right to draw merchandise 

in a bonded warehouse has been transferred. 

Indurating furnace means a furnace where unfired 

taconite pellets, called green balls, are hardened at high 

temperatures to produce fired pellets for use in a blast 

furnace. Types of indurating furnaces include straight gate 

and grate kiln furnaces.

Industrial greenhouse gases means nitrous oxide or any 

fluorinated greenhouse gas.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 106 of 520

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In-line kiln/raw mill means a system in a portland 

cement production process where a dry kiln system is 

integrated with the raw mill so that all or a portion of 

the kiln exhaust gases are used to perform the drying 

operation of the raw mill, with no auxiliary heat source 

used. In this system the kiln is capable of operating 

without the raw mill operating, but the raw mill cannot 

operate without the kiln gases, and consequently, the raw 

mill does not generate a separate exhaust gas stream.

Intermittent bleed pneumatic devices mean automated 

flow control devices powered by pressurized natural gas and 

used for maintaining a process condition such as liquid 

level, pressure, delta-pressure and temperature. These are 

snap-acting or throttling devices that discharge the full 

volume of the actuator intermittently when control action 

is necessary, but does not bleed continuously.

Isobutane is a paraffinic branch chain hydrocarbon 

with molecular formula C4H10.

Isobutylene is an olefinic branch chain hydrocarbon 

with molecular formula C4H8.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 107 of 520

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Kerosene is a light petroleum distillate with a 

maximum distillation temperature of 400 °F at the 10-

percent recovery point, a final maximum boiling point of 

572 °F, a minimum flash point of 100 °F, and a maximum 

freezing point of -22 °F. Included are No. 1-K and No. 2-K, 

distinguished by maximum sulfur content (0.04 and 0.30 

percent of total mass, respectively), as well as all other 

grades of kerosene called range or stove oil. Excluded is 

kerosene-type jet fuel (see definition herein).

Kerosene-type jet fuel means a kerosene-based product 

used in commercial and military turbojet and turboprop 

aircraft. The product has a maximum distillation 

temperature of 400 °F at the 10 percent recovery point and 

a final maximum boiling point of 572 °F. Included are Jet 

A, Jet A-1, JP-5, and JP-8.

Kiln means an oven, furnace, or heated enclosure used 

for thermally processing a mineral or mineral-based 

substance.

Landfill means an area of land or an excavation in 

which wastes are placed for permanent disposal and that is 

not a land application unit, surface impoundment, injection 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 108 of 520

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well, or waste pile as those terms are defined under 40 CFR 

257.2.

Landfill gas means gas produced as a result of 

anaerobic decomposition of waste materials in the landfill. 

Landfill gas generally contains 40 to 60 percent methane on 

a dry basis, typically less than 1 percent non-methane 

organic chemicals, and the remainder being carbon dioxide.

Liberated means released from coal and surrounding 

rock strata during the mining process. This includes both 

methane emitted from the ventilation system and methane 

drained from degasification systems.

Lime is the generic term for a variety of chemical 

compounds that are produced by the calcination of limestone 

or dolomite. These products include but are not limited to 

calcium oxide, high-calcium quicklime, calcium hydroxide, 

hydrated lime, dolomitic quicklime, and dolomitic hydrate.

Liquid/Slurry means a manure management component in 

which manure is stored as excreted or with some minimal 

addition of water to facilitate handling and is stored in 

either tanks or earthen ponds, usually for periods less 

than one year.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 109 of 520

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Low-bleed pneumatic devices mean automated flow 

control devices powered by pressurized natural gas and used 

for maintaining a process condition such as liquid level, 

pressure, delta-pressure and temperature. Part of the gas 

power stream that is regulated by the process condition 

flows to a valve actuator controller where it vents 

continuously (bleeds) to the atmosphere at a rate equal to 

or less than six standard cubic feet per hour.

Lubricants include all grades of lubricating oils, 

from spindle oil to cylinder oil to those used in greases. 

Petroleum lubricants may be produced from distillates or 

residues.

Makeup chemicals means carbonate chemicals (e.g., 

sodium and calcium carbonates) that are added to the 

chemical recovery areas of chemical pulp mills to replace 

chemicals lost in the process.

Manure composting means the biological oxidation of a 

solid waste including manure usually with bedding or 

another organic carbon source typically at thermophilic 

temperatures produced by microbial heat production. There 

are four types of composting employed for manure
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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management: Static, in vessel, intensive windrow and 

passive windrow. Static composting typically occurs in an 

enclosed channel, with forced aeration and continuous 

mixing. In vessel composting occurs in piles with forced 

aeration but no mixing. Intensive windrow composting occurs

in windrows with regular turning for mixing and aeration. 

Passive windrow composting occurs in windrows with 

infrequent turning for mixing and aeration.

Maximum rated heat input capacity means the hourly 

heat input to a unit (in mmBtu/hr), when it combusts the 

maximum amount of fuel per hour that it is capable of 

combusting on a steady state basis, as of the initial 

installation of the unit, as specified by the manufacturer.

Maximum rated input capacity means the maximum 

charging rate of a municipal waste combustor unit expressed 

in tons per day of municipal solid waste combusted, 

calculated according to the procedures under 40 CFR 

60.58b(j).

Mcf means thousand cubic feet.

Methane conversion factor means the extent to which 

the CH4 producing capacity (Bo) is realized in each type of 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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treatment and discharge pathway and system. Thus, it is an 

indication of the degree to which the system is anaerobic.

Methane correction factor means an adjustment factor 

applied to the methane generation rate to account for 

portions of the landfill that remain aerobic. The methane 

correction factor can be considered the fraction of the 

total landfill waste volume that is ultimately disposed of 

in an anaerobic state. Managed landfills that have soil or 

other cover materials have a methane correction factor of 

1. 

Methanol (CH3OH) is an alcohol as described in 

"Oxygenates."

Midgrade gasoline has an octane rating greater than or 

equal to 88 and less than or equal to 90. This definition 

applies to the midgrade categories of Conventional-Summer, 

Conventional-Winter, Reformulated-Summer, and ReformulatedWinter. For midgrade categories of RBOB-Summer, RBOBWinter, CBOB-Summer, and CBOB-Winter, this definition 

refers to the expected octane rating of the finished 

gasoline after oxygenate has been added to the RBOB or 

CBOB.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Miscellaneous products include all refined petroleum 

products not defined elsewhere. It includes, but is not 

limited to, naphtha-type jet fuel (Jet B and JP-4), 

petrolatum lube refining by-products (aromatic extracts and 

tars), absorption oils, ram-jet fuel, petroleum rocket 

fuels, synthetic natural gas feedstocks, waste feedstocks, 

and specialty oils. It excludes organic waste sludges, tank 

bottoms, spent catalysts, and sulfuric acid.

MMBtu means million British thermal units.

Motor gasoline (finished) means a complex mixture of 

volatile hydrocarbons, with or without additives, suitably 

blended to be used in spark ignition engines. Motor 

gasoline includes conventional gasoline, reformulated 

gasoline, and all types of oxygenated gasoline. Gasoline 

also has seasonal variations in an effort to control ozone 

levels. This is achieved by lowering the Reid Vapor 

Pressure (RVP) of gasoline during the summer driving 

season. Depending on the region of the country the RVP is 

lowered to below 9.0 psi or 7.8 psi. The RVP may be further 

lowered by state regulations.

Mscf means thousand standard cubic feet.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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MTBE (methyl tertiary butyl ether, (CH3)3COCH3) is an 

ether as described in "Oxygenates." 

Municipal solid waste landfill or MSW landfill means 

an entire disposal facility in a contiguous geographical 

space where household waste is placed in or on land. An MSW 

landfill may also receive other types of RCRA Subtitle D 

wastes (40 CFR 257.2) such as commercial solid waste, 

nonhazardous sludge, conditionally exempt small quantity 

generator waste, and industrial solid waste. Portions of an 

MSW landfill may be separated by access roads, public 

roadways, or other public right-of-ways. An MSW landfill 

may be publicly or privately owned.

Municipal solid waste or MSW means solid phase 

household, commercial/retail, and/or institutional waste. 

Household waste includes material discarded by single and 

multiple residential dwellings, hotels, motels, and other 

similar permanent or temporary housing establishments or 

facilities. Commercial/retail waste includes material 

discarded by stores, offices, restaurants, warehouses, nonmanufacturing activities at industrial facilities, and 

other similar establishments or facilities. Institutional 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 114 of 520

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waste includes material discarded by schools, nonmedical 

waste discarded by hospitals, material discarded by nonmanufacturing activities at prisons and government 

facilities, and material discarded by other similar 

establishments or facilities. Household, commercial/retail, 

and institutional wastes include yard waste, refuse-derived 

fuel, and motor vehicle maintenance materials. Insofar as 

there is separate collection, processing and disposal of 

industrial source waste streams consisting of used oil, 

wood pallets, construction, renovation, and demolition 

wastes (which includes, but is not limited to, railroad 

ties and telephone poles), paper, clean wood, plastics, 

industrial process or manufacturing wastes, medical waste, 

motor vehicle parts or vehicle fluff, or used tires that do 

not contain hazardous waste identified or listed under 42 

U.S.C. §6921, such wastes are not municipal solid waste. 

However, such wastes qualify as municipal solid waste where 

they are collected with other municipal solid waste or are 

otherwise combined with other municipal solid waste for 

processing and/or disposal.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 115 of 520

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Municipal wastewater treatment plant means a series of 

treatment processes used to remove contaminants and 

pollutants from domestic, business, and industrial 

wastewater collected in city sewers and transported to a 

centralized wastewater treatment system such as a publicly 

owned treatment works (POTW).

N2O means nitrous oxide.

Naphthas (< 401 °F) is a generic term applied to a 

petroleum fraction with an approximate boiling range 

between 122 °F and 400 °F. The naphtha fraction of crude 

oil is the raw material for gasoline and is composed

largely of paraffinic hydrocarbons.

Natural gas means a naturally occurring mixture of 

hydrocarbon and non-hydrocarbon gases found in geologic 

formations beneath the earth's surface, of which the 

principal constituent is methane. Natural gas may be field

quality or pipeline quality.

Natural gas driven pneumatic pump means a pump that 

uses pressurized natural gas to move a piston or diaphragm, 

which pumps liquids on the opposite side of the piston or 

diaphragm.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Natural gas liquids (NGLs) means those hydrocarbons in 

natural gas that are separated from the gas as liquids 

through the process of absorption, condensation, 

adsorption, or other methods. Generally, such liquids 

consist of ethane, propane, butanes, and pentanes plus. 

Bulk NGLs refers to mixtures of NGLs that are sold or 

delivered as undifferentiated product from natural gas 

processing plants.

Natural gasoline means a mixture of liquid 

hydrocarbons (mostly pentanes and heavier hydrocarbons) 

extracted from natural gas. It includes isopentane. 

NIST means the United States National Institute of 

Standards and Technology.

Nitric acid production line means a series of reactors 

and absorbers used to produce nitric acid. 

Nitrogen excreted is the nitrogen that is excreted by 

livestock in manure and urine.

Non-crude feedstocks means any petroleum product or 

natural gas liquid that enters the refinery to be further 

refined or otherwise used on site.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Non-recovery coke oven battery means a group of ovens 

connected by common walls and operated as a unit, where 

coal undergoes destructive distillation under negative 

pressure to produce coke, and which is designed for the 

combustion of the coke oven gas from which by-products are 

not recovered.

North American Industry Classification System (NAICS)

code(s) means the six-digit code(s) that represents the 

product(s)/activity(s)/ service(s) at a facility or 

supplier as listed in the Federal Register and defined 

in “North American Industrial Classification System 

Manual 2007,” available from the U.S. Department of 

Commerce, National Technical Information Service, 

Alexandria, VA 22312, phone (703) 605–6000 or (800) 553–

6847. http://www.census.gov/eos/www/naics/.

Oil-fired unit means a stationary combustion unit that 

derives more than 50 percent of its annual heat input from 

the combustion of fuel oil, and the remainder of its annual 

heat input from the combustion of natural gas or other 

gaseous fuels. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Open-ended valve or lines (OELs) means any valve, 

except pressure relief valves, having one side of the valve 

seat in contact with process fluid and one side open to 

atmosphere, either directly or through open piping.

Operating hours means the duration of time in which a 

process or process unit is utilized; this excludes 

shutdown, maintenance, and standby.

Operational change means, for purposes of §98.3(b), a 

change in the type of feedstock or fuel used, a change in 

operating hours, or a change in process production rate.

Operator means any person who operates or supervises a 

facility or supplier.

Other oils (> 401 °F) are oils with a boiling range 

equal to or greater than 401 °F that are generally intended 

for use as a petrochemical feedstock and are not defined 

elsewhere.

Outer Continental Shelf means all submerged lands 

lying seaward and outside of the area of lands beneath 

navigable waters as defined in 43 U.S.C. 1331, and of which 

the subsoil and seabed appertain to the United States and 

are subject to its jurisdiction and control.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Owner means any person who has legal or equitable 

title to, has a leasehold interest in, or control of a 

facility or supplier, except a person whose legal or 

equitable title to or leasehold interest in the facility or 

supplier arises solely because the person is a limited 

partner in a partnership that has legal or equitable title 

to, has a leasehold interest in, or control of the facility 

or supplier shall not be considered an “owner” of the 

facility or supplier. 

Oxygenates means substances which, when added to 

gasoline, increase the oxygen content of the gasoline. 

Common oxygenates are ethanol, methyl tertiary butyl ether 

(MTBE), ethyl tertiary butyl ether (ETBE), tertiary amyl 

methyl ether (TAME), diisopropyl ether (DIPE), and 

methanol. 

Pasture/Range/Paddock means the manure from pasture 

and range grazing animals is allowed to lie as deposited, 

and is not managed.

Pentanes plus, or C5+, is a mixture of hydrocarbons 

that is a liquid at ambient temperature and pressure, and 

consists mostly of pentanes (five carbon chain) and higher 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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carbon number hydrocarbons. Pentanes plus includes, but is 

not limited to, normal pentane, isopentane, hexanes-plus 

(natural gasoline), and plant condensate.

Perfluorocarbons or PFCs means a class of greenhouse 

gases consisting on the molecular level of carbon and 

fluorine.

Petrochemical means methanol, acrylonitrile, ethylene, 

ethylene oxide, ethylene dichloride, and any form of carbon 

black.

Petrochemical feedstocks means feedstocks derived from 

petroleum for the manufacture of chemicals, synthetic 

rubber, and a variety of plastics. This category is usually 

divided into naphthas less than 401 °F and other oils 

greater than 401 °F.

Petroleum means oil removed from the earth and the oil 

derived from tar sands and shale.

Petroleum coke means a black solid residue, obtained 

mainly by cracking and carbonizing of petroleum derived 

feedstocks, vacuum bottoms, tar and pitches in processes 

such as delayed coking or fluid coking. It consists mainly 

of carbon (90 to 95 percent), has low ash content, and may 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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be used as a feedstock in coke ovens. This product is also 

known as marketable coke or catalyst coke.

Petroleum product means all refined and semi-refined 

products that are produced at a refinery by processing 

crude oil and other petroleum-based feedstocks, including 

petroleum products derived from co-processing biomass and 

petroleum feedstock together, but not including plastics or 

plastic products. Petroleum products may be combusted for 

energy use, or they may be used either for non-energy 

processes or as non-energy products. The definition of 

petroleum product for importers and exporters excludes

waxes.

Physical address, with respect to a United States 

parent company as defined in this section, means the 

street address, city, state and zip code of that 

company’s physical location.

Pit storage below animal confinement (deep pits) means 

the collection and storage of manure typically below a 

slatted floor in an enclosed animal confinement facility. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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This usually occurs with little or no added water for 

periods less than one year.

Portable means designed and capable of being carried 

or moved from one location to another. Indications of 

portability include but are not limited to wheels, skids, 

carrying handles, dolly, trailer, or platform. Equipment is 

not portable if any one of the following conditions exists: 

(1) The equipment is attached to a foundation.

(2) The equipment or a replacement resides at the same 

location for more than 12 consecutive months.

(3) The equipment is located at a seasonal facility 

and operates during the full annual operating period of the 

seasonal facility, remains at the facility for at least two 

years, and operates at that facility for at least three 

months each year.

(4) The equipment is moved from one location to 

another in an attempt to circumvent the portable residence 

time requirements of this definition. 

Poultry manure with litter means a manure management 

system component that is similar to cattle and swine deep 

bedding except usually not combined with a dry lot or 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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pasture. The system is typically used for poultry breeder 

flocks and for the production of meat type chickens 

(broiler) and other fowl.

Poultry manure without litter means a manure 

management system component that may manage manure in a 

liquid form, similar to open pits in enclosed animal 

confinement facilities. These systems may alternatively be 

designed and operated to dry manure as it accumulates. The 

latter is known as a high-rise manure management system and 

is a form of passive windrow manure composting when 

designed and operated properly.

Precision of a measurement at a specified level(e.g., 

one percent of full scale or one percent of the value 

measured) means that 95 percent of repeat measurements made 

by a device or technique are within the range bounded by 

the mean of the measurements plus or minus the specified 

level. 

Premium grade gasoline is gasoline having an antiknock 

index, i.e., octane rating, greater than 90. This 

definition applies to the premium grade categories of 

Conventional-Summer, Conventional-Winter, Reformulated-
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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Summer, and Reformulated-Winter. For premium grade 

categories of RBOB-Summer, RBOB-Winter, CBOB-Summer, and 

CBOB-Winter, this definition refers to the expected octane 

rating of the finished gasoline after oxygenate has been 

added to the RBOB or CBOB.

Pressed and blown glass means glass which is pressed, 

blown, or both, into products such as light bulbs, glass 

fiber, technical glass, and other products listed in NAICS 

327212.

Pressure relief device or pressure relief valve or 

pressure safety valve means a safety device used to prevent 

operating pressures from exceeding the maximum allowable 

working pressure of the process equipment. A common 

pressure relief device is but not limited to a springloaded pressure relief valve. Devices that are actuated 

either by a pressure of less than or equal to 2.5 psig or 

by a vacuum are not pressure relief devices.

Primary fuel means the fuel that provides the greatest 

percentage of the annual heat input to a stationary fuel 

combustion unit.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Process emissions means the emissions from industrial 

processes (e.g., cement production, ammonia production) 

involving chemical or physical transformations other than 

fuel combustion. For example, the calcination of carbonates 

in a kiln during cement production or the oxidation of 

methane in an ammonia process results in the release of 

process CO2 emissions to the atmosphere. Emissions from fuel 

combustion to provide process heat are not part of process 

emissions, whether the combustion is internal or external 

to the process equipment.

Process unit means the equipment assembled and 

connected by pipes and ducts to process raw materials and 

to manufacture either a final product or an intermediate 

used in the onsite production of other products. The 

process unit also includes the purification of recovered 

byproducts.

Process vent means means a gas stream that: Is 

discharged through a conveyance to the atmosphere either 

directly or after passing through a control device; 

originates from a unit operation, including but not limited 

to reactors (including reformers, crackers, and furnaces, 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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Greenhouse Gases Rule. 

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and separation equipment for products and recovered 

byproducts); and contains or has the potential to contain 

GHG that is generated in the process. Process vent does not 

include safety device discharges, equipment leaks, gas 

streams routed to a fuel gas system or to a flare, 

discharges from storage tanks.

Propane is a paraffinic hydrocarbon with molecular 

formula C3H8. 

Propylene is an olefinic hydrocarbon with molecular 

formula C3H6.

Pulp mill lime kiln means the combustion units (e.g., 

rotary lime kiln or fluidized bed calciner) used at a kraft 

or soda pulp mill to calcine lime mud, which consists 

primarily of calcium carbonate, into quicklime, which is 

calcium oxide.

Pushing means the process of removing the coke from 

the coke oven at the end of the coking cycle. Pushing 

begins when coke first begins to fall from the oven into 

the quench car and ends when the quench car enters the 

quench tower.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Raw mill means a ball and tube mill, vertical roller 

mill or other size reduction equipment, that is not part of 

an in-line kiln/raw mill, used to grind feed to the 

appropriate size. Moisture may be added or removed from the 

feed during the grinding operation. If the raw mill is used 

to remove moisture from feed materials, it is also, by 

definition, a raw material dryer. The raw mill also 

includes the air separator associated with the raw mill.

RBOB-Summer (reformulated blendstock for oxygenate 

blending) means a petroleum product which, when blended 

with a specified type and percentage of oxygenate, meets 

the definition of Reformulated-Summer.

RBOB-Winter (reformulated blendstock for oxygenate 

blending) means a petroleum product which, when blended 

with a specified type and percentage of oxygenate, meets 

the definition of Reformulated-Winter.

Reciprocating compressor means a piece of equipment 

that increases the pressure of a process natural gas or CO2

by positive displacement, employing linear movement of a 

shaft driving a piston in a cylinder.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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Reciprocating compressor rod packing means a series of 

flexible rings in machined metal cups that fit around the 

reciprocating compressor piston rod to create a seal 

limiting the amount of compressed natural gas or CO2 that 

escapes to the atmosphere.

Re-condenser means heat exchangers that cool 

compressed boil-off gas to a temperature that will condense 

natural gas to a liquid.

Reformulated—Summer refers to finished gasoline 

formulated for use in motor vehicles, the composition and 

properties of which meet the requirements of the 

reformulated gasoline regulations promulgated by the U.S. 

Environmental Protection Agency under 40 CFR 80.40 and 40 

CFR 80.41, and summer RVP standards required under 40 CFR 

80.27 or as specified by the state. Reformulated gasoline 

excludes Reformulated Blendstock for Oxygenate Blending 

(RBOB) as well as other blendstock.

Reformulated—Winter refers to finished gasoline 

formulated for use in motor vehicles, the composition and 

properties of which meet the requirements of the 

reformulated gasoline regulations promulgated by the U.S. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Environmental Protection Agency under 40 CFR 80.40 and 40 

CFR 80.41, but which do not meet summer RVP standards 

required under 40 CFR 80.27 or as specified by the state. 

Note: This category includes Oxygenated Fuels Program 

Reformulated Gasoline (OPRG). Reformulated gasoline 

excludes Reformulated Blendstock for Oxygenate Blending 

(RBOB) as well as other blendstock.

Regular grade gasoline is gasoline having an 

antiknock index, i.e., octane rating, greater than or equal 

to 85 and less than 88. This definition applies to the 

regular grade categories of Conventional-Summer, 

Conventional-Winter, Reformulated-Summer, and ReformulatedWinter. For regular grade categories of RBOB-Summer, RBOBWinter, CBOB-Summer, and CBOB-Winter, this definition 

refers to the expected octane rating of the finished 

gasoline after oxygenate has been added to the RBOB or 

CBOB.

Rendered animal fat, or tallow, means fats extracted 

from animals which are generally used as a feedstock in 

making biodiesel. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Research and development means those activities 

conducted in process units or at laboratory bench-scale 

settings whose purpose is to conduct research and 

development for new processes, technologies, or products 

and whose purpose is not for the manufacture of products 

for commercial sale, except in a de minimis manner.

Residual Fuel Oil No. 5 (Navy Special) is a 

classification for the heavier fuel oil generally used in 

steam powered vessels in government service and inshore 

power plants. It has a minimum flash point of 131 °F.

Residual Fuel Oil No. 6 (a.k.a. Bunker C) is a 

classification for the heavier fuel oil generally used for 

the production of electric power, space heating, vessel 

bunkering and various industrial purposes. It has a minimum 

flash point of 140 °F.

Residuum is residue from crude oil after distilling 

off all but the heaviest components, with a boiling range 

greater than 1,000 °F. 

Road oil is any heavy petroleum oil, including 

residual asphaltic oil used as a dust palliative and 

surface treatment on roads and highways. It is generally 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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produced in six grades, from 0, the most liquid, to 5, the 

most viscous.

Rotary lime kiln means a unit with an inclined 

rotating drum that is used to produce a lime product from 

limestone by calcination.

Safety device means a closure device such as a 

pressure relief valve, frangible disc, fusible plug, or any 

other type of device which functions exclusively to prevent 

physical damage or permanent deformation to a unit or its 

air emission control equipment by venting gases or vapors 

directly to the atmosphere during unsafe conditions 

resulting from an unplanned, accidental, or emergency 

event. A safety device is not used for routine venting of 

gases or vapors from the vapor headspace underneath a cover 

such as during filling of the unit or to adjust the 

pressure in response to normal daily diurnal ambient 

temperature fluctuations. A safety device is designed to 

remain in a closed position during normal operations and 

open only when the internal pressure, or another relevant 

parameter, exceeds the device threshold setting applicable 

to the air emission control equipment as determined by the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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owner or operator based on manufacturer recommendations, 

applicable regulations, fire protection and prevention 

codes and practices, or other requirements for the safe 

handling of flammable, combustible, explosive, reactive, or 

hazardous materials.

Sales oil means produced crude oil or condensate 

measured at the production lease automatic custody transfer 

(LACT) meter or custody transfer tank gauge.

Semi-refined petroleum product means all oils 

requiring further processing. Included in this category are 

unfinished oils which are produced by the partial refining 

of crude oil and include the following: Naphthas and 

lighter oils; kerosene and light gas oils; heavy gas oils;

and residuum, and all products that require further 

processing or the addition of blendstocks.

Sendout means, in the context of a local distribution 

company, the total deliveries of natural gas to customers 

over a specified time interval (typically hour, day, month, 

or year). Sendout is the sum of gas received through the 

city gate, gas withdrawn from on-system storage or peak 

shaving plants, and gas produced and delivered into the 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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distribution system; and is net of any natural gas injected 

into on-system storage. It comprises gas sales, exchange, 

deliveries, gas used by company, and unaccounted for gas. 

Sendout is measured at the city gate station, and other onsystem receipt points from storage, peak shaving, and 

production. 

Sensor means a device that measures a physical 

quantity/quality or the change in a physical 

quantity/quality, such as temperature, pressure, flow rate, 

pH, or liquid level.

SF6 means sulfur hexafluoride.

Shutdown means the cessation of operation of an 

emission source for any purpose.

Silicon carbide means an artificial abrasive produced 

from silica sand or quartz and petroleum coke.

Sinter process means a process that produces a fused 

aggregate of fine iron-bearing materials suited for use in 

a blast furnace. The sinter machine is composed of a 

continuous traveling grate that conveys a bed of ore fines 

and other finely divided iron-bearing material and fuel 

(typically coke breeze), a burner at the feed end of the 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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grate for ignition, and a series of downdraft windboxes 

along the length of the strand to support downdraft 

combustion and heat sufficient to produce a fused sinter 

product.

Site means any combination of one or more graded pad 

sites, gravel pad sites, foundations, platforms, or the 

immediate physical location upon which equipment is 

physically located.

Smelting furnace means a furnace in which lead-bearing 

materials, carbon-containing reducing agents, and fluxes 

are melted together to form a molten mass of material 

containing lead and slag.

Solid by-products means plant matter such as vegetable 

waste, animal materials/wastes, and other solid biomass, 

except for wood, wood waste, and sulphite lyes (black 

liquor).

Solid storage is the storage of manure, typically for 

a period of several months, in unconfined piles or stacks. 

Manure is able to be stacked due to the presence of a 

sufficient amount of bedding material or loss of moisture 

by evaporation.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Sour gas means any gas that contains significant 

concentrations of hydrogen sulfide. Sour gas may include 

untreated fuel gas, amine stripper off-gas, or sour water 

stripper gas. 

Sour natural gas means natural gas that contains 

significant concentrations of hydrogen sulfide (H2S)and/or 

carbon dioxide (CO2) that exceed the concentrations 

specified for commercially saleable natural gas delivered 

from transmission and distribution pipelines.

Special naphthas means all finished products with the 

naphtha boiling range (290° to 470 °F) that are generally 

used as paint thinners, cleaners or solvents. These 

products are refined to a specified flash point. Special 

naphthas include all commercial hexane and cleaning 

solvents conforming to ASTM Specification D1836-07, 

Standard Specification for Commercial Hexanes, and D235-02

(Reapproved 2007), Standard Specification for Mineral 

Spirits (Petroleum Spirits) (Hydrocarbon Dry Cleaning 

Solvent), respectively. Naphthas to be blended or marketed 

as motor gasoline or aviation gasoline, or that are to be 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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used as petrochemical and synthetic natural gas (SNG) 

feedstocks are excluded.

Spent liquor solids means the dry weight of the solids 

in the spent pulping liquor that enters the chemical 

recovery furnace or chemical recovery combustion unit.

Spent pulping liquor means the residual liquid 

collected from on-site pulping operations at chemical pulp 

facilities that is subsequently fired in chemical recovery 

furnaces at kraft and soda pulp facilities or chemical 

recovery combustion units at sulfite or semi-chemical pulp 

facilities.

Standard conditions or standard temperature and 

pressure (STP), for the purposes of this part, means either 

60 or 68 degrees Fahrenheit and 14.7 pounds per square inch 

absolute.

Steam reforming means a catalytic process that 

involves a reaction between natural gas or other light 

hydrocarbons and steam. The result is a mixture of 

hydrogen, carbon monoxide, carbon dioxide, and water.

Still gas means any form or mixture of gases produced 

in refineries by distillation, cracking, reforming, and 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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other processes. The principal constituents are methane, 

ethane, ethylene, normal butane, butylene, propane, and 

propylene.

Storage tank means a vessel (excluding sumps) that is 

designed to contain an accumulation of crude oil, 

condensate, intermediate hydrocarbon liquids, or produced 

water and that is constructed entirely of non-earthen 

materials (e.g., wood, concrete, steel, plastic) that 

provide structural support.

Sulfur recovery plant means all process units which 

recover sulfur or produce sulfuric acid from hydrogen 

sulfide (H2S) and/or sulfur dioxide (SO2) from a common 

source of sour gas at a petroleum refinery. The sulfur 

recovery plant also includes sulfur pits used to store the 

recovered sulfur product, but it does not include secondary 

sulfur storage vessels or loading facilities downstream of 

the sulfur pits. For example, a Claus sulfur recovery plant 

includes: Reactor furnace and waste heat boiler, catalytic 

reactors, sulfur pits, and, if present, oxidation or 

reduction control systems, or incinerator, thermal 

oxidizer, or similar combustion device. Multiple sulfur 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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recovery units are a single sulfur recovery plant only when 

the units share the same source of sour gas. Sulfur 

recovery units that receive source gas from completely 

segregated sour gas treatment systems are separate sulfur 

recovery plants.

Supplemental fuel means a fuel burned within a 

petrochemical process that is not produced within the 

process itself.

Supplier means a producer, importer, or exporter in 

any supply category included in Table A-5, as defined by 

the corresponding subpart of this part.

Sweet gas is natural gas with low concentrations of 

hydrogen sulfide (H2S) and/or carbon dioxide (CO2) that does 

not require (or has already had) acid gas treatment to meet 

pipeline corrosion-prevention specifications for 

transmission and distribution.

Taconite iron ore processing means an industrial 

process that separates and concentrates iron ore from 

taconite, a low grade iron ore, and heats the taconite in 

an indurating furnace to produce taconite pellets that are 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 139 of 520

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used as the primary feed material for the production of 

iron in blast furnaces at integrated iron and steel plants.

TAME means tertiary amyl methyl ether, 

(CH3)2(C2H5)COCH3).

Trace concentrations means concentrations of less than 

0.1 percent by mass of the process stream.

Transform means to use and entirely consume (except 

for trace concentrations) nitrous oxide or fluorinated GHGs 

in the manufacturing of other chemicals for commercial 

purposes. Transformation does not include burning of 

nitrous oxide.

Transshipment means the continuous shipment of nitrous 

oxide or a fluorinated GHG from a foreign state of origin 

through the United States or its territories to a second 

foreign state of final destination, as long as the shipment 

does not enter into United States jurisdiction. A 

transshipment, as it moves through the United States or its 

territories, cannot be re-packaged, sorted or otherwise 

changed in condition.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 140 of 520

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Trona means the raw material (mineral) used to 

manufacture soda ash; hydrated sodium bicarbonate carbonate 

(e.g.Na2CO3.NaHCO3.2H2O).

Ultimate analysis means the determination of the 

percentages of carbon, hydrogen, nitrogen, sulfur, and 

chlorine and (by difference) oxygen in the gaseous products 

and ash after the complete combustion of a sample of an 

organic material.

Unfinished oils are all oils requiring further 

processing, except those requiring only mechanical 

blending.

United States means the 50 States, the District of 

Columbia, the Commonwealth of Puerto Rico, American Samoa, 

the Virgin Islands, Guam, and any other Commonwealth, 

territory or possession of the United States, as well as 

the territorial sea as defined by Presidential Proclamation 

No. 5928.

United States parent company(s) means the highestlevel United States company(s) with an ownership interest 

in the facility or supplier as of December 31 of the year 

for which data are being reported.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 141 of 520

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Unstabilized crude oil means, for the purposes of this 

part, crude oil that is pumped from the well to a pipeline 

or pressurized storage vessel for transport to the refinery 

without intermediate storage in a storage tank at 

atmospheric pressures. Unstabilized crude oil is 

characterized by having a true vapor pressure of 5 pounds 

per square inch absolute (psia) or greater.

Used oil means a petroleum-derived or syntheticallyderived oil whose physical properties have changed as a 

result of handling or use, such that the oil cannot be used 

for its original purpose. Used oil consists primarily of 

automotive oils ( e.g., used motor oil, transmission oil,

hydraulic fluids, brake fluid, etc. ) and industrial oils ( 

e.g., industrial engine oils, metalworking oils, process 

oils, industrial grease, etc ).

Valve means any device for halting or regulating the 

flow of a liquid or gas through a passage, pipeline, inlet, 

outlet, or orifice; including, but not limited to, gate, 

globe, plug, ball, butterfly and needle valves.

Vapor recovery system means any equipment located at 

the source of potential gas emissions to the atmosphere or 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 142 of 520

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to a flare, that is composed of piping, connections, and, 

if necessary, flow-inducing devices, and that is used for 

routing the gas back into the process as a product and/or 

fuel.

Vaporization unit means a process unit that performs 

controlled heat input to vaporize LNG to supply 

transmission and distribution pipelines or consumers with 

natural gas.

Vegetable oil means oils extracted from vegetation 

that are generally used as a feedstock in making biodiesel.

Ventilation well or shaft means a well 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 system means a system that is used to 

control the concentration of methane and other gases within 

mine working areas through mine ventilation, rather than a 

mine degasification system. A ventilation system consists 

of fans that move air through the mine workings to dilute 

methane concentrations. This includes all ventilation 

shafts and wells at the underground coal mine.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 143 of 520

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Volatile solids are the organic material in livestock 

manure and consist of both biodegradable and nonbiodegradable fractions.

Waelz kiln means an inclined rotary kiln in which 

zinc–containing materials are charged together with a 

carbon reducing agent (e.g., petroleum coke, metallurgical 

coke, or anthracite coal).

Waxes means a solid or semi-solid material at 77 °F 

consisting of a mixture of hydrocarbons obtained or derived 

from petroleum fractions, or through a Fischer-Tropsch type 

process, in which the straight chained paraffin series 

predominates. This includes all marketable wax, whether 

crude or refined, with a congealing point between 80 (or 

85) and 240 °F and a maximum oil content of 50 weight 

percent.

Well completions means the process that allows for the 

flow of petroleum or natural gas from newly drilled wells 

to expel drilling and reservoir fluids and test the 

reservoir flow characteristics, steps which may vent 

produced gas to the atmosphere via an open pit or tank. 

Well completion also involves connecting the well bore to 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 144 of 520

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the reservoir, which may include treating the formation or 

installing tubing, packer(s), or lifting equipment, steps 

that do not significantly vent natural gas to the 

atmosphere. This process may also include high-rate 

flowback of injected gas, water, oil, and proppant used to 

fracture or re-fracture and prop open new fractures in 

existing lower permeability gas reservoirs, steps that may 

vent large quantities of produced gas to the atmosphere.

Well workover means the process(es) of performing one 

or more of a variety of remedial operations on producing 

petroleum and natural gas wells to try to increase 

production. This process also includes high-rate flowback 

of injected gas, water, oil, and proppant used to refracture and prop-open new fractures in existing low 

permeability gas reservoirs, steps that may vent large 

quantities of produced gas to the atmosphere.

Wellhead means the piping, casing, tubing and 

connected valves protruding above the earth’s surface for 

an oil and/or natural gas well. The wellhead ends where the 

flow line connects to a wellhead valve. Wellhead equipment 

includes all equipment, permanent and portable, located on 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 145 of 520

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the improved land area (i.e. well pad) surrounding one or 

multiple wellheads.

Wet natural gas means natural gas in which water vapor 

exceeds the concentration specified for commercially 

saleable natural gas delivered from transmission and 

distribution pipelines. This input stream to a natural gas 

dehydrator is referred to as “wet gas.”

Wood residuals means materials recovered from three 

principal sources: Municipal solid waste (MSW); 

construction and demolition debris; and primary timber 

processing. Wood residuals recovered from MSW include 

wooden furniture, cabinets, pallets and containers, scrap 

lumber (from sources other than construction and demolition 

activities), and urban tree and landscape residues. Wood 

residuals from construction and demolition debris originate 

from the construction, repair, remodeling and demolition of 

houses and non-residential structures. Wood residuals from 

primary timber processing include bark, sawmill slabs and 

edgings, sawdust, and peeler log cores. Other sources of 

wood residuals include, but are not limited to, railroad 

ties, telephone and utility poles, pier and dock timbers, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 146 of 520

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wastewater process sludge from paper mills, trim, sander 

dust, and sawdust from wood products manufacturing 

(including resinated wood product residuals), and logging 

residues.

Wool fiberglass means fibrous glass of random texture, 

including fiberglass insulation, and other products listed 

in NAICS 327993.

Working capacity, for the purposes of subpart TT of 

this part, means the maximum volume or mass of waste that 

is actually placed in the landfill from an individual or 

representative type of container (such as a tank, truck, or 

roll-off bin) used to convey wastes to the landfill, taking 

into account that the container may not be able to be 100 

percent filled and/or 100 percent emptied for each load.

You means an owner or operator subject to Part 98.

Zinc smelters means a facility engaged in the 

production of zinc metal, zinc oxide, or zinc alloy 

products from zinc sulfide ore concentrates, zinc calcine, 

or zinc-bearing scrap and recycled materials through the 

use of pyrometallurgical techniques involving the reduction 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 147 of 520

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and volatization of zinc-bearing feed materials charged to 

a furnace.

§98.7 What standardized methods are incorporated by 

reference into this part?

The materials listed in this section are incorporated 

by reference in the corresponding sections noted. These 

incorporations by reference were approved by the Director 

of Federal Register in accordance with 5 U.S.C. 552(a) and 

1 CFR part 51. These materials are incorporated as they 

exist on the date of approval, and a notice of any change 

in the materials will be published in the Federal Register. 

The materials are available for purchase at the 

corresponding address in this section. The materials are 

available for inspection at the EPA Docket Center, Public 

Reading Room, EPA West Building, Room 3334, 1301 

Constitution Avenue, NW, Washington, DC, phone (202) 566-

1744 and at the National Archives and Records 

Administration (NARA). For information on the availability 

of this material at NARA, call 202-741-6030, or go to: 

http://www.archives.gov/federal_register/code_of_federal_re

gulations/ibr_ locations.html. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 148 of 520

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(a) [Reserved]

(b) [Reserved

 (c) The following material is available for purchase 

from the ASM International, 9639 Kinsman Road, Materials 

Park, OH 44073, (440) 338-5151, 

http://www.asminternational.org.

(1) ASM CS-104 UNS No. G10460 - Alloy Digest April 

1985 (Carbon Steel of Medium Carbon Content), incorporation 

by reference (IBR) approved for §98.174(b).

(2) [Reserved]

(d) The following material is available for purchase 

from the American Society of Mechanical Engineers (ASME), 

Three Park Avenue, New York, NY 10016-5990, (800) 843-2763, 

http://www.asme.org.

(1) ASME MFC–3M–2004 Measurement of Fluid Flow in 

Pipes Using Orifice, Nozzle, and Venturi, incorporation by 

reference (IBR) approved for §98.124(m)(1), §98.324(e), 

§98.354(d), §98.354(h), §98.344(c) and §98.364(e).

(2) ASME MFC–4M–1986 (Reaffirmed 1997) Measurement of 

Gas Flow by Turbine Meters, IBR approved for §98.124(m)(2), 

§98.324(e), §98.344(c), §98.354(h), and §98.364(e).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 149 of 520

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(3) ASME MFC–5M–1985 (Reaffirmed 1994) Measurement of 

Liquid Flow in Closed Conduits Using Transit-Time 

Ultrasonic Flow Meters, IBR approved for §98.124(m)(3) and 

§98.354(d).

(4) ASME MFC–6M–1998 Measurement of Fluid Flow in 

Pipes Using Vortex Flowmeters, IBR approved for 

§98.124(m)(4), §98.324(e), §98.344(c), §98.354(h), and 

§98.364(e).

(5) ASME MFC–7M–1987 (Reaffirmed 1992) Measurement of 

Gas Flow by Means of Critical Flow Venturi Nozzles, IBR 

approved for §98.124(m)(5), §98.324(e), §98.344(c), 

§98.354(h), and §98.364(e).

(6) ASME MFC–9M–1988 (Reaffirmed 2001) Measurement of 

Liquid Flow in Closed Conduits by Weighing Method, IBR 

approved for §98.124(m)(6).

(7) ASME MFC–11M–2006 Measurement of Fluid Flow by 

Means of Coriolis Mass Flowmeters, IBR approved for 

§98.124(m)(7), §98.324(e), §98.344(c), and §98.354(h).

(8) ASME MFC–14M–2003 Measurement of Fluid Flow Using 

Small Bore Precision Orifice Meters, IBR approved for 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 150 of 520

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§98.124(m)(8), §98.324(e), §98.344(c), §98.354(h), and 

§98.364(e).

(9) ASME MFC–16–2007 Measurement of Liquid Flow in 

Closed Conduits with Electromagnetic Flow Meters, IBR 

approved for §98.354(d).

(10) ASME MFC–18M–2001 Measurement of Fluid Flow Using 

Variable Area Meters, IBR approved for §98.324(e), 

§98.344(c), §98.354(h), and §98.364(e).

(e) The following material is available for purchase 

from the American Society for Testing and Material (ASTM), 

100 Barr Harbor Drive, P.O. Box CB700, West Conshohocken, 

Pennsylvania 19428-B2959, (800) 262-1373, 

http://www.astm.org.

(1) ASTM C25-06 Standard Test Method for Chemical 

Analysis of Limestone, Quicklime, and Hydrated Lime, 

incorporation by reference (IBR) approved for §98.114(b),

§98.174(b), §98.184(b), §98.194(c), and §98.334(b).

(2) ASTM C114-09 Standard Test Methods for Chemical 

Analysis of Hydraulic Cement, IBR approved for §98.84(a),

§98.84(b), and §98.84(c).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 151 of 520

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(3) ASTM D235-02 (Reapproved 2007) Standard 

Specification for Mineral Spirits (Petroleum Spirits) 

(Hydrocarbon Dry Cleaning Solvent), IBR approved for §98.6.

(4) ASTM D240–02 (Reapproved 2007) Standard Test 

Method for Heat of Combustion of Liquid Hydrocarbon Fuels 

by Bomb Calorimeter, IBR approved for §98.254(e).

(5) ASTM D388-05 Standard Classification of Coals by 

Rank, IBR approved for §98.6.

(6) ASTM D910-07a Standard Specification for Aviation 

Gasolines, IBR approved for §98.6.

(7) [Reserved]

(8) ASTM D1826–94 (Reapproved 2003) Standard Test 

Method for Calorific (Heating) Value of Gases in Natural 

Gas Range by Continuous Recording Calorimeter, IBR approved 

for §98.254(e).

(9) ASTM D1836-07 Standard Specification for 

Commercial Hexanes, IBR approved for §98.6.

(10) ASTM D1945–03 Standard Test Method for Analysis 

of Natural Gas by Gas Chromatography, IBR approved for 

§98.74(c), §98.164(b), §98.244(b), §98.254(d), §98.324(d), 

§98.354(g), and §98.344(b).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 152 of 520

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(11) ASTM D1946–90 (Reapproved 2006) Standard Practice 

for Analysis of Reformed Gas by Gas Chromatography, IBR 

approved for §98.74(c), §98.164(b), §98.254(d), §98.324(d), 

§98.344(b), §98.354(g), and §98.364(c).

(12) ASTM D2013-07 Standard Practice for Preparing 

Coal Samples for Analysis, IBR approved for §98.164(b).

(13) ASTM D2234/D2234M-07 Standard Practice for 

Collection of a Gross Sample of Coal, IBR approved for 

§98.164(b).

(14) ASTM D2502–04 Standard Test Method for Estimation 

of Mean Relative Molecular Mass of Petroleum Oils From 

Viscosity Measurements, IBR approved for §98.74(c).

(15) ASTM D2503–92 (Reapproved 2007) Standard Test 

Method for Relative Molecular Mass (Molecular Weight) of 

Hydrocarbons by Thermoelectric Measurement of Vapor 

Pressure, IBR approved for §98.74(c) and §98.254(d)(6).

(16) ASTM D2505-88 (Reapproved 2004)e1 Standard Test 

Method for Ethylene, Other Hydrocarbons, and Carbon Dioxide 

in High-Purity Ethylene by Gas Chromatography, IBR approved 

for §98.244(b).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(17) ASTM D2597-94 (Reapproved 2004) Standard Test 

Method for Analysis of Demethanized Hydrocarbon Liquid 

Mixtures Containing Nitrogen and Carbon Dioxide by Gas 

Chromatography, IBR approved for §98.164(b).

(18) ASTM D3176-89 (Reapproved 2002) Standard Practice 

for Ultimate Analysis of Coal and Coke, IBR approved for 

§98.74(c), §98.164(b), §98.244(b), §98.254(i), §98.284(c),

§98.284(d), §98.314(c), §98.314(d), and §98.314(f).

(19) ASTM D3238–95 (Reapproved 2005) Standard Test 

Method for Calculation of Carbon Distribution and 

Structural Group Analysis of Petroleum Oils by the n-d-M 

Method, IBR approved for §98.74(c) and §98.164(b).

(20) ASTM D3588–98 (Reapproved 2003) Standard Practice 

for Calculating Heat Value, Compressibility Factor, and 

Relative Density of Gaseous Fuels, IBR approved for 

§98.254(e).

(21) ASTM D3682-01 (Reapproved 2006) Standard Test 

Method for Major and Minor Elements in Combustion Residues 

from Coal Utilization Processes, IBR approved for 

§98.144(b).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 154 of 520

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(22) ASTM D4057-06 Standard Practice for Manual 

Sampling of Petroleum and Petroleum Products, IBR approved 

for §98.164(b).

(23) ASTM D4177-95 (Reapproved 2005) Standard Practice 

for Automatic Sampling of Petroleum and Petroleum Products, 

IBR approved for §98.164(b).

(24) ASTM D4809–06 Standard Test Method for Heat of 

Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter 

(Precision Method), IBR approved for §98.254(e).

(25) ASTM D4891–89 (Reapproved 2006) Standard Test 

Method for Heating Value of Gases in Natural Gas Range by 

Stoichiometric Combustion, IBR approved for §98.254(e) and 

§98.324(d).

(26) ASTM D5291–02 (Reapproved 2007) Standard Test 

Methods for Instrumental Determination of Carbon, Hydrogen, 

and Nitrogen in Petroleum Products and Lubricants, IBR 

approved for §98.74(c), §98.164(b), §98.244(b), and 

§98.254(i).

(27) ASTM D5373–08 Standard Test Methods for 

Instrumental Determination of Carbon, Hydrogen, and 

Nitrogen in Laboratory Samples of Coal, IBR approved for 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 155 of 520

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§98.74(c), §98.114(b), §98.164(b), §98.174(b), §98.184(b), 

§98.244(b), §98.254(i), §98.274(b), §98.284(c), §98.284(d), 

§98.314(c), §98.314(d), §98.314(f), and §98.334(b).

(28) [Reserved]

(29) ASTM D6060-96 (Reapproved 2001) Standard Practice 

for Sampling of Process Vents With a Portable Gas 

Chromatograph, IBR approved for §98.244(b).

(30) ASTM D6348–03 Standard Test Method for 

Determination of Gaseous Compounds by Extractive Direct 

Interface Fourier Transform Infrared (FTIR) Spectroscopy, 

IBR approved for §98.54(b), §98.124(e)(2), §98.224(b), and 

§98.414(n).

(31) ASTM D6609-08 Standard Guide for Part-Stream 

Sampling of Coal, IBR approved for §98.164(b).

(32) ASTM D6751-08 Standard Specification for 

Biodiesel Fuel Blend Stock (B100) for Middle Distillate 

Fuels, IBR approved for §98.6.

(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).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 156 of 520

Draft – Deliberative – Do Not Cite, Quote, or Release

(34) ASTM D6883-04 Standard Practice for Manual 

Sampling of Stationary Coal from Railroad Cars, Barges, 

Trucks, or Stockpiles, IBR approved for §98.164(b). 

(35) ASTM D7430-08ae1 Standard Practice for Mechanical 

Sampling of Coal, IBR approved for §98.164(b).

(36) 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, IBR approved for §98.34(d), §98.34(e), 

and §98.36(e).

(37) ASTM E359-00 (Reapproved 2005)e1 Standard Test 

Methods for Analysis of Soda Ash (Sodium Carbonate), IBR 

approved for §98.294(a) and §98.294(b).

(38) ASTM E1019-08 Standard Test Methods for 

Determination of Carbon, Sulfur, Nitrogen, and Oxygen in 

Steel, Iron, Nickel, and Cobalt Alloys by Various 

Combustion and Fusion Techniques, IBR approved for 

§98.174(b).

(39) [Reserved]

(40) ASTM E1915-07a Standard Test Methods for Analysis 

of Metal Bearing Ores and Related Materials by Combustion 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 157 of 520

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Infrared-Absorption Spectrometry, IBR approved for 

§98.174(b).

(41) ASTM E1941-04 Standard Test Method for 

Determination of Carbon in Refractory and Reactive Metals 

and Their Alloys, IBR approved for §98.114(b), §98.184(b),

§98.334(b).

(42) ASTM UOP539-97 Refinery Gas Analysis by Gas 

Chromatography, IBR approved for §98.164(b), §98.244(b),

§98.254(d), §98.324(d), §98.344(b), and §98.354(g).

(43) ASTM D1941-91 (Reapproved 2007) Standard Test 

Method for Open Channel Flow Measurement of Water with the 

Parshall Flume, approved June 15, 2007, IBR approved for 

§98.354(d).

(44) ASTM D5614-94 (Reapproved 2008) Standard Test 

Method for Open Channel Flow Measurement of Water with 

Broad-Crested Weirs, approved October 1, 2008, IBR approved 

for §98.354(d).

(45) ASTM D6349-09 Standard Test Method for 

Determination of Major and Minor Elements in Coal, Coke, 

and Solid Residues from Combustion of Coal and Coke by 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 158 of 520

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Inductively Coupled Plasma—Atomic Emission Spectrometry, 

IBR approved for §98.144(b).

(46) ASTM D2879-97 (Reapproved 2007) Standard Test 

Method for Vapor Pressure-Temperature Relationship and 

Initial Decomposition Temperature of Liquids by 

Isoteniscope (ASTM D2879), approved May 1, 2007, IBR 

approved for §98.128.

(47) ASTM D7359-08 Standard Test Method for Total 

Fluorine, Chlorine and Sulfur in Aromatic Hydrocarbons and 

Their Mixtures by Oxidative Pyrohydrolytic Combustion 

followed by Ion Chromatography Detection (Combustion Ion 

Chromatography-CIC) (ASTM D7359), approved October 15, 

2008, IBR approved for §98.124(e)(2).

(48) ASTM D2593–93 (Reapproved 2009) Standard Test 

Method for Butadiene Purity and Hydrocarbon Impurities by 

Gas Chromatography, approved July 1, 2009, IBR approved for 

§98.244(b)(4)(xi).

(49) ASTM D7633–10 Standard Test Method for Carbon 

Black—Carbon Content, approved May 15, 2010, IBR approved 

for §98.244(b)(4)(xii).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 159 of 520

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(f) The following material is available for purchase 

from the Gas Processors Association (GPA), 6526 East 60th 

Street, Tulsa, Oklahoma 74143, (918) 493-3872, 

http://www.gasprocessors.com.

(1) [Reserved]

(2) GPA 2261–00 Analysis for Natural Gas and Similar 

Gaseous Mixtures by Gas Chromatography, IBR approved for 

§98.164(b), §98.254(d), §98.344(b), and §98.354(g).

(g) The following material is available for purchase 

from the International Standards Organization (ISO), 1, ch. 

de la Voie-Creuse, Case postale 56, CH-1211 Geneva 20, 

Switzerland, +41 22 749 01 11, 

http://www.iso.org/iso/home.htm.

(1) ISO 3170: Petroleum liquids—Manual sampling -

Third Edition 2004-02-01, IBR approved for §98.164(b).

(2) ISO 3171: Petroleum Liquids—Automatic pipeline 

sampling - Second Edition 1988-12-01, IBR approved for 

§98.164(b).

(3) [Reserved]

(4) ISO/TR 15349-1: 1998, Unalloyed steel—

Determination of low carbon content. Part 1: Infrared 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 160 of 520

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absorption method after combustion in an electric 

resistance furnace (by peak separation) (1998-10-15) -

First Edition, IBR approved for §98.174(b).

(5) ISO/TR 15349-3: 1998, Unalloyed steel—

Determination of low carbon content. Part 3: Infrared 

absorption method after combustion in an electric 

resistance furnace (with preheating) (1998-10-15) - First 

Edition, IBR approved for §98.174(b).

(h) The following material is available for purchase 

from the National Lime Association (NLA), 200 North Glebe 

Road, Suite 800, Arlington, Virginia 22203, (703) 243-5463, 

http://www.lime.org.

(1) CO2 Emissions Calculation Protocol for the Lime 

Industry—English Units Version, February 5, 2008 Revision—

National Lime Association, incorporation by reference (IBR) 

approved for §98.194(c) and §98.194(e).

(2) [Reserved]

(i) The following material is available for purchase 

from the National Institute of Standards and Technology 

(NIST), 100 Bureau Drive, Stop 1070, Gaithersburg, MD 

20899-1070, (800) 877-8339, http://www.nist.gov/index.html.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 161 of 520

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(1) Specifications, Tolerances, and Other Technical 

Requirements For Weighing and Measuring Devices, NIST 

Handbook 44 (2009), incorporation by reference (IBR) 

approved for §98.244(b), §98.254(h), and §98.344(a).

(2) [Reserved]

(j) The following material is available for purchase 

from the Technical Association of the Pulp and Paper 

Industry (TAPPI), 15 Technology Parkway South, Norcross, GA 

30092, (800) 332-8686, http://www.tappi.org. 

(1) T650 om-05 Solids Content of Black Liquor, TAPPI, 

incorporation by reference (IBR) approved for §98.276(c) 

and §98.277(d).

(2) T684 om-06 Gross Heating Value of Black Liquor, 

TAPPI, incorporation by reference (IBR) approved for 

§98.274(b).

(k) The following material is available for purchase 

from Standard Methods, at http://www.standardmethods.org, 

(877) 574-1233; or, through a joint publication agreement 

from the American Public Health Association (APHA), PO Box 

933019, Atlanta, GA 31193-3019, (888) 320-APHA (2742), 

http://www.apha.org/publications/pubscontact/. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 162 of 520

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(1) Method 2540G Total, Fixed, and Volatile Solids in 

Solid and Semisolid Samples, IBR approved for §98.464(b). 

(2) [Reserved] 

(l) The following material is available from the U.S. 

Department of Labor, Mine Safety and Health Administration, 

1100 Wilson Boulevard, 21st Floor, Arlington, VA 22209-

3939, (202) 693-9400, www.msha.gov. 

(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). 

(2) [Reserved] 

(m) The following material is available from the U.S. 

Environmental Protection Agency, 1200 Pennsylvania Avenue, 

NW, Washington, D.C. 20460, (202) 272-0167,http://

www.epa.gov. 

(1) NPDES Compliance Inspection Manual, Chapter 5, 

Sampling, EPA 305-X-04-001, July 2004, 

http://www.epa.gov/compliance/monitoring/programs/cwa/npdes 

.html, IBR approved for §98.354(c). 

(2) U.S. EPA NPDES Permit Writers’ Manual, Section 

7.1.3, Sample Collection Methods, EPA 833-B-96-003, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 163 of 520

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December 1996, http://www.epa.gov/npdes/pubs/owm0243.pdf, 

IBR approved for §98.354(c). 

(3) Protocol for Measuring Destruction or Removal 

Efficiency (DRE) of Fluorinated Greenhouse Gas Abatement 

Equipment in Electronics Manufacturing, Version 1, EPA–430–

R–10–003, March 2010 (EPA 430–R–10–003), 

http://www.epa.gov/semiconductorpfc/documents/dre_protocol.pdf, IBR approved for 

§98.94(f)(4)(i), §98.94(g)(3), §98.97(d)(4), §98.98, 

§98.124(e)(2), and §98.414(n)(1).

(4) Emissions Inventory Improvement Program, Volume 

II: Chapter 16, Methods for Estimating Air Emissions from 

Chemical Manufacturing Facilities, August 2007, Final, 

http://www.epa.gov/ttnchie1/eiip/techreport/volume02/index.

html, IBR approved for §98.123(c)(1)(i)(A). 

(5) Protocol for Equipment Leak Emission Estimates, 

EPA-453/R-95-017, November 1995 (EPA-453/R-95-017), 

http://www.epa.gov/ttnchie1/efdocs/equiplks.pdf, IBR 

approved for §98.123(d)(1)(i), §98.123(d)(1)(ii), 

§98.123(d)(1)(iii), and §98.124(f)(2).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 164 of 520

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(6) Tracer Gas Protocol for the Determination of 

Volumetric Flow Rate Through the Ring Pipe of the Xact 

Multi-Metals Monitoring System, also known as Other Test 

Method 24, (Tracer Gas Protocol), Eli Lilly and Company 

Tippecanoe Laboratories, September 2006, 

http://www.epa.gov/ttn/emc/prelim/otm24.pdf, IBR approved 

for §98.124(e)(1)(ii). 

(7) Approved Alternative Method 012: An Alternate 

Procedure for Stack Gas Volumetric Flow Rate Determination 

(Tracer Gas) (ALT-012), U.S. Environmental Protection 

Agency Emission Measurement Center, May 23, 1994, 

http://www.epa.gov/ttn/emc/approalt/alt-012.pdf, IBR 

approved for §98.124(e)(1)(ii).

8) Protocol for Measurement of Tetrafluoromethane (CF4) 

and Hexafluoroethane (C2F6) Emissions from Primary Aluminum 

Production (2008), http://www.epa.gov/highgwp/aluminumpfc/documents/measureprotocol.pdf, IBR approved for 

§98.64(a).

(9) AP 42, Section 5.2, Transportation and Marketing 

of Petroleum Liquids, July 2008, (AP 42, Section 5.2); 

http://www.epa.gov/ttn/chief/ap42/ch05/final/c05s02.pdf; in 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 165 of 520

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Chapter 5, Petroleum Industry, of AP 42, Compilation of Air 

Pollutant Emission Factors, 5th Edition, Volume I, IBR 

approved for §98.253(n).

(10) Method 9060A, Total Organic Carbon, Revision 1, 

November 2004 (Method 9060A), 

http://www.epa.gov/osw/hazard/testmethods/sw846/pdfs/9060a.

pdf; in EPA Publication No. SW–846, “Test Methods for 

Evaluating Solid Waste, Physical/Chemical Methods,” Third 

Edition, IBR approved for §98.244(b)(4)(viii).

(11) Method 8031, Acrylonitrile By Gas Chromatography, 

Revision 0, September 1994 (Method 8031), 

http://www.epa.gov/osw/hazard/testmethods/sw846/pdfs/8031.p

df; in EPA Publication No. SW–846, “Test Methods for 

Evaluating Solid Waste, Physical/Chemical Methods,” Third 

Edition, IBR approved for §98.244(b)(4)(viii).

(12) Method 8021B, Aromatic and Halogenated Volatiles 

By Gas Chromatography Using Photoionization and/or 

Electrolytic Conductivity Detectors, Revision 2, December 

1996 (Method 8021B). 

http://www.epa.gov/osw/hazard/testmethods/sw846/pdfs/8021b.

pdf; in EPA Publication No. SW–846, “Test Methods for 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 166 of 520

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Evaluating Solid Waste, Physical/Chemical Methods,” Third 

Edition, IBR approved for §98.244(b)(4)(viii).

(13) Method 8015C, Nonhalogenated Organics By Gas 

Chromatography, Revision 3, February 2007 (Method 8015C). 

http://www.epa.gov/osw/hazard/testmethods/sw846/pdfs/8015c.

pdf; in EPA Publication No. SW–846, “Test Methods for 

Evaluating Solid Waste, Physical/Chemical Methods,” Third 

Edition, IBR approved for §98.244(b)(4)(viii).

(14) AP 42, Section 7.1, Organic Liquid Storage Tanks, 

November 2006 (AP 42, Section 7.1), 

http://www.epa.gov/ttn/chief/ap42/ch07/final/c07s01.pdf; in 

Chapter 7, Liquid Storage Tanks, of AP 42, Compilation of 

Air Pollutant Emission Factors, 5th Edition, Volume I, IBR 

approved for §98.253(m)(1) and §98.256(o)(2)(i).

(n) The following material is available from the 

International SEMATECH Manufacturing Initiative, 2706 

Montopolis Drive, Austin, Texas 78741, (512) 356-3500, 

http://ismi.sematech.org

(1) Guideline for Environmental Characterization of 

Semiconductor Process Equipment, International SEMATECH 

Manufacturing Initiative Technology Transfer #06124825A-
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 167 of 520

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ENG, December 22, 2006 (International SEMATECH #06124825AENG), IBR approved for §98.94(d), §98.94(d)(1), §98.94(e), 

§98.94(e)(1), §98.94(g)(1), §98.96(f)(4), and §98.97(b)(1). 

(2) Guidelines for Environmental Characterization of 

Semiconductor Equipment, International SEMATECH Technology 

Transfer #01104197A-XFR, December 4, 2001 (International 

SEMATECH #01104197A-XFR), IBR approved for §98.94(d), 

§98.94(d)(1), §98.94(e), §98.94(e)(1), §98.94(g)(2), 

§98.96(f)(4), and §98.97(b)(1).

(o) [Reserved]

(p) The following material is available for purchase 

from the American Association of Petroleum Geologists, 1444 

South Boulder Avenue, Tulsa, Oklahoma 74119, (918) 584-

2555, http://www.aapg.org.

(1) Geologic Note: AAPG-CSD Geologic Provinces Code 

Map: AAPG Bulletin, Prepared by Richard F. Meyer, Laure G. 

Wallace, and Fred J. Wagner, Jr., Volume 75, Number 10 

(October 1991), pages 1644-1651, IBR approved for §98.238.

(2) Alaska Geological Province Boundary Map, Compiled 

by the American Association of Petroleum Geologists 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 168 of 520

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Committee on Statistics of Drilling in cooperation with the 

USGS, 1978, IBR approved for §98.238.

(q) The following material is available from the 

Energy Information Administration (EIA), 1000 Independence 

Ave., SW, Washington, DC 20585, (202) 586-8800, 

http://www.eia.doe.gov/pub/oil_gas/natural_gas/data_publica

tions/field_code_master_list/current/pdf/fcml_all.pdf.

(1) Oil and Gas Field Code Master List 2008, 

DOE/EIA0370(08), January 2009, IBR approved for §98.238.

(2) [Reserved]

§98.8 What are the compliance and enforcement provisions 

of this part? 

Any violation of any requirement of this part shall be 

a violation of the Clean Air Act, including section 114 (42 

U.S.C. §7414). A violation includes but is not limited to 

failure to report GHG emissions, failure to collect data 

needed to calculate GHG emissions, failure to continuously 

monitor and test as required, failure to retain records 

needed to verify the amount of GHG emissions, and failure 

to calculate GHG emissions following the methodologies 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 169 of 520

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specified in this part. Each day of a violation constitutes 

a separate violation.

§98.9 Addresses.

All requests, notifications, and communications to the 

Administrator pursuant to this part, other than submittal 

of the annual GHG report; the certificate of 

representation; and other requests, notifications or 

communications that can be submitted through the electronic 

greenhouse gas reporting tool, shall be submitted to the 

following address:

(a) For U.S. mail.

Director, Climate Change Division

1200 Pennsylvania Ave., NW

Mail Code: 6207J

Washington, DC 20460

(b) For package deliveries.

Director, Climate Change Division

1310 L St, NW

Washington, DC 20005
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 170 of 520

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Table A-1 of Subpart A—Global Warming Potentials (100-Year 

Time Horizon)

Name CAS # Chemical formula

Global 

warming 

potential 

(100 yr.)

Carbon dioxide 124-38-9 CO2 1

Methane 74-82-8 CH4 21

Nitrous oxide 10024-97-2 N2O 310

HFC-23 75-46-7 CHF3 11,700

HFC-32 75-10-5 CH2F2 650

HFC-41 593-53-3 CH3F 150

HFC-125 354-33-6 C2HF5 2,800

HFC-134 359-35-3 C2H2F4 1,000

HFC-134a 811-97-2 CH2FCF3 1,300

HFC-143 430-66-0 C2H3F3 300

HFC-143a 420-46-2 C2H3F3 3,800

HFC-152 624-72-6 CH2FCH2F 53

HFC-152a 75-37-6 CH3CHF2 140

HFC-161 353-36-6 CH3CH2F 12

HFC-227ea 431-89-0 C3HF7 2,900

HFC-236cb 677-56-5 CH2FCF2CF3 1,340

HFC-236ea 431-63-0 CHF2CHFCF3 1,370

HFC-236fa 690-39-1 C3H2F6 6,300

HFC-245ca 679-86-7 C3H3F5 560

HFC-245fa 460-73-1 CHF2CH2CF3 1,030

HFC-365mfc 406-58-6 CH3CF2CH2CF3 794

HFC-43-10mee 138495-42-8 CF3CFHCFHCF2CF3 1,300

Sulfur hexafluoride 2551-62-4 SF6 23,900

Trifluoromethyl sulphur 

pentafluoride 373-80-8

SF5CF3 17,700

Nitrogen trifluoride 7783-54-2 NF3 17,200

PFC-14 

(Perfluoromethane) 75-73-0

CF4 6,500

PFC-116 

(Perfluoroethane) 76-16-4

C2F6 9,200

PFC-218 

(Perfluoropropane) 76-19-7

C3F8 7,000

Perfluorocyclopropane 931-91-9 c-C3F6 17,340

PFC-3-1-10 

(Perfluorobutane) 355-25-9

C4F10 7,000

Perfluorocyclobutane 115-25-3 c-C4F8 8,700
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 171 of 520

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Table A-1 of Subpart A—Global Warming Potentials (100-Year 

Time Horizon)

Name CAS # Chemical formula

Global 

warming 

potential 

(100 yr.)

PFC-4-1-12 

(Perfluoropentane) 678-26-2

C5F12 7,500

PFC-5-1-14

(Perfluorohexane) 355-42-0

C6F14 7,400

PFC-9-1-18 306-94-5 C10F18 7,500

HCFE-235da2 (Isoflurane) 26675-46-7 CHF2OCHClCF3 350

HFE-43-10pccc (H-Galden 

1040x) E1730133 CHF2OCF2OC2F4OCHF2 1,870

HFE-125 3822-68-2 CHF2OCF3 14,900

HFE-134 1691-17-4 CHF2OCHF2 6,320

HFE-143a 421-14-7 CH3OCF3 756

HFE-227ea 2356-62-9 CF3CHFOCF3 1,540

HFE-236ca12 (HG-10) 78522-47-1 CHF2OCF2OCHF2 2,800

HFE-236ea2 (Desflurane) 57041-67-5 CHF2OCHFCF3 989

HFE-236fa 20193-67-3 CF3CH2OCF3 487

HFE-245cb2 22410-44-2 CH3OCF2CF3 708

HFE-245fa1 84011-15-4 CHF2CH2OCF3 286

HFE-245fa2 1885-48-9 CHF2OCH2CF3 659

HFE-254cb2 425-88-7 CH3OCF2CHF2 359

HFE-263fb2 460-43-5 CF3CH2OCH3 11

HFE-329mcc2 67490-36-2 CF3CF2OCF2CHF2 919

HFE-338mcf2 156053-88-2 CF3CF2OCH2CF3 552

HFE-338pcc13 (HG-01) 188690-78-0 CHF2OCF2CF2OCHF2 1,500

HFE-347mcc3 28523-86-6 CH3OCF2CF2CF3 575

HFE-347mcf2 E1730135 CF3CF2OCH2CHF2 374

HFE-347pcf2 406-78-0 CHF2CF2OCH2CF3 580

HFE-356mec3 382-34-3 CH3OCF2CHFCF3 101

HFE-356pcc3 160620-20-2 CH3OCF2CF2CHF2 110

HFE-356pcf2 E1730137 CHF2CH2OCF2CHF2 265

HFE-356pcf3 35042-99-0 CHF2OCH2CF2CHF2 502

HFE-365mcf3 378-16-5 CF3CF2CH2OCH3 11

HFE-374pc2 512-51-6 CH3CH2OCF2CHF2 557

HFE-449sl (HFE-7100)

Chemical blend

163702-07-6

163702-08-7

C4F9OCH3

(CF3)2CFCF2OCH3

297

HFE-569sf2 (HFE-7200)

Chemical blend

163702-05-4

163702-06-5

C4F9OC2H5

(CF3)2CFCF2OC2H5

59
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rights, obligations, responsibilities, expectations, or benefits 

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Table A-1 of Subpart A—Global Warming Potentials (100-Year 

Time Horizon)

Name CAS # Chemical formula

Global 

warming 

potential 

(100 yr.)

Sevoflurane 28523-86-6 CH2FOCH(CF3)2 345

HFE-356mm1 13171-18-1 (CF3)2CHOCH3 27

HFE-338mmz1 26103-08-2 CHF2OCH(CF3)2 380

(Octafluorotetramethylene)hydroxymethyl group NA X-(CF2)4CH(OH)-X 73

HFE-347mmy1 22052-84-2 CH3OCF(CF3)2 343

Bis(trifluoromethyl)-

methanol 920-66-1 (CF3)2CHOH 195

2,2,3,3,3-

pentafluoropropanol 422-05-9 CF3CF2CH2OH 42

PFPMIE NA

CF3OCF(CF3)CF2OCF2OC

F3 10,300

NA = not available

Table A-2 to Subpart A of Part 98—Units of Measure 

Conversions.

To convert from To Multiply by

Kilograms (kg) Pounds (lbs) 2.20462

Pounds (lbs) Kilograms (kg) 0.45359

Pounds (lbs) Metric tons 4.53592 x 10-4

Short tons Pounds (lbs) 2,000

Short tons Metric tons 0.90718

Metric tons Short tons 1.10231

Metric tons Kilograms (kg) 1,000

Cubic meters (m3) Cubic feet (ft3) 35.31467

Cubic feet (ft3) Cubic meters (m3) 0.028317

Gallons (liquid, US) Liters (l) 3.78541

Liters (l) Gallons (liquid, US) 0.26417

Barrels of Liquid 

Fuel (bbl)

Cubic meters (m3) 0.15891

Cubic meters (m3) Barrels of Liquid 

Fuel (bbl)

6.289

Barrels of Liquid 

Fuel (bbl)

Gallons (liquid, US) 42

Gallons (liquid, US) Barrels of Liquid 

Fuel (bbl)

0.023810
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To convert from To Multiply by

Gallons (liquid, US) Cubic meters (m3) 0.0037854

Liters (l) Cubic meters (m3) 0.001

Feet (ft) Meters (m) 0.3048

Meters (m) Feet (ft) 3.28084

Miles (mi) Kilometers (km) 1.60934

Kilometers (km) Miles (mi) 0.62137

Square feet (ft2) Acres 2.29568 x 10-5

Square meters (m2) Acres 2.47105 x 10-4

Square miles (mi2) Square kilometers 

(km2)

2.58999

Degrees Celsius (oC) Degrees Fahrenheit 

(oF)

oC = (5/9) x ( oF32)

Degrees Fahrenheit 

(oF)

Degrees Celsius (oC) oF = (9/5) x oC + 32

Degrees Celsius (oC) Kelvin (K) K = oC + 273.15

Kelvin (K) Degrees Rankine (oR) 1.8

Joules Btu 9.47817 x 10-4

Btu MMBtu 1 x 10-6

Pascals (Pa) Inches of Mercury 

(in Hg)

2.95334 x 10-4

Inches of Mercury 

(inHg)

Pounds per square 

inch (psi)

0.49110

Pounds per square 

inch (psi)

Inches of Mercury 

(in Hg)

2.03625

Table A-3 of Subpart A of Part 98—Source Category List for 

§98.2(a)(1)

Source Categoriesa Applicable in 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).
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Source Categoriesa Applicable in 2010 and Future Years

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 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.

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.
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Table A-4 to Subpart A of Part 98—Source Category List for

§98.2(a)(2)

Source Categoriesa Applicable in 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 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.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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Table A-5 to Subpart A of Part 98 —Supplier Category List 

for §98.2(a)(4)

Supplier Categoriesa Applicable in 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
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

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Supplier Categoriesa Applicable in 2010 and Future Years

Natural gas and natural gas liquids suppliers (subpart NN):

 (A) All fractionators.

 (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

 (B) Importers of industrial greenhouse gases 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 industrial greenhouse gases with annual bulk 

exports of N2O, fluorinated GHG, and CO2 that in combination are 

equivalent to 25,000 metric tons CO2e or more
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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Supplier Categoriesa Applicable in 2010 and Future Years

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 Categoriesa Applicable in 2011 and Future 

Years

Importers and exporters of fluorinated greenhouse gases 

contained in pre-charged equipment or closed-cell foams (subpart 

QQ): 

(A) Importers of an annual quantity of fluorinated greenhouse 

gases contained in pre-charged equipment or closed-cell foams 

that is equivalent to 25,000 metric tons CO2e or more.

(B) Exporters of an annual quantity of fluorinated greenhouse 

gases contained in pre-charged equipment or closed-cell foams 

that is equivalent to 25,000 metric tons CO2e or more.

aSuppliers are defined in each applicable subpart.

TABLE A–6 TO SUBPART A—DATA ELEMENTS THAT ARE INPUTS TO 

EMISSION EQUATIONS AND FOR WHICH THE

REPORTING DEADLINE IS CHANGED TO AUGUST 31, 2011

SubpartRule Citation (40 Specific Data Elements for 
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CFR part 98) Which Reporting Date is Changed 

(“All” means that the date is 

changed for all data elements 

in the cited paragraph)

A 98.3(d)(3)(v) All.

C 98.36(b)(9)(iii) Only estimate of the heat 

input.

C 98.36(c)(2)(ix) Only estimate of the heat input 

from each type of fuel listed 

in Table C–2.

C 98.36(d)(1)(iv) All.

C 98.36(d)(2)(ii)(G) All.

C 98.36(d)(2)(iii)(G) All.

C 98.36(e)(2)(i) All.

C 98.36(e)(2)(ii)(A) All.

C 98.36(e)(2)(ii)(C) Only HHV value for each 

calendar month in which HHV 

determination is required.

C 98.36(e)(2)(ii)(D) All.

C 98.36(e)(2)(iv)(A) All.

C 98.36(e)(2)(iv)(C) All.

C 98.36(e)(2)(iv)(F) All.

C 98.36(e)(2)(iv)(G) All.

C 98.36(e)(2)(vi)(C) Only stack gas flow rate and 

moisture content.

C 98.36(e)(2)(viii)(A) All.

C 98.36(e)(2)(viii)(B) All.

C 98.36(e)(2)(viii)(C) All.

C 98.36(e)(2)(ix)(D) All.
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C 98.36(e)(2)(ix)(E) All.

C 98.36(e)(2)(ix)(F) All.

C 98.36(e)(2)(x)(A) All.

C 98.36(e)(2)(xi) All.

E 98.56(b) All.

E 98.56(c) All.

E 98.56(g) All.

E 98.56(h) All.

E 98.56(j)(1) All.

E 98.56(j)(3) All.

E 98.56(j)(4) All.

E 98.56(j)(5) All.

E 98.56(j)(6) All.

E 98.56(l) All.

F 98.66(a) All.

F 98.66(c)(2) All.

F 98.66(c)(3) Only smelter-specific slope 

coefficients and overvoltage 

emission factors.

F 98.66(e)(1) Only annual anode consumption 

(No CEMS).

F 98.66(f)(1) Only annual paste consumption 

(No CEMS).

F 98.66(g) All.

G 98.76(b)(2) All.

G 98.76(b)(7) All.

G 98.76(b)(8) All.
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G 98.76(b)(9) All.

G 98.76(b)(10) All.

G 98.76(b)(11) All.

H 98.86(b)(2) All.

H 98.86(b)(5) All.

H 98.86(b)(6) All.

H 98.86(b)(8) All.

H 98.86(b)(10) All.

H 98.86(b)(11) All.

H 98.86(b)(12) All.

H 98.86(b)(13) All.

H 98.86(b)(15) Only monthly kiln-specific 

clinker factors (if used) for 

each kiln.

K 98.116(b) Only annual production by 

product from each EAF (No 

CEMS).

K 98.116(e)(4) All.

K 98.116(e)(5) All.

N 98.146(b)(2) Only annual quantity of 

carbonate based-raw material 

charged to each continuous 

glass melting furnace.

N 98.146(b)(4) All.

N 98.146(b)(6) All.

O 98.156(a)(2) All.

O 98.156(a)(7) All.

O 98.156(a)(8) All.
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O 98.156(a)(9) All.

O 98.156(a)(10) All.

O 98.156(b)(1) All.

O 98.156(b)(2) All.

O 98.156(d)(1) All.

O 98.156(d)(2) All.

O 98.156(d)(3) All.

O 98.156(d)(4) All.

O 98.156(d)(5) All.

O 98.156(e)(1) All.

P 98.166(b)(2) All.

P 98.166(b)(5) All.

P 98.166(b)(6) All.

Q 98.176(b) Only annual quantity taconite 

pellets, coke, iron, and raw 

steel (No CEMS).

Q 98.176(e)(1) All.

Q 98.176(e)(3) All.

Q 98.176(e)(4) All.

Q 98.176(f)(1) All.

Q 98.176(f)(2) All.

Q 98.176(f)(3) All.

Q 98.176(f)(4) All.

Q 98.176(g) All.

R 98.186(b)(6) All.

R 98.186(b)(7) All.

S 98.196(b)(2) All.
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S 98.196(b)(3) All.

S 98.196(b)(5) All.

S 98.196(b)(6) All.

S 98.196(b)(8) All.

S 98.196(b)(10) All.

S 98.196(b)(11) All.

S 98.196(b)(12) All.

U 98.216(b) All.

U 98.216(e)(1) All.

U 98.216(e)(2) All.

U 98.216(f)(1) All.

U 98.216(f)(2) All.

V 98.226(c) All.

V 98.226(d) All.

V 98.226(i) All.

V 98.226(j) All.

V 98.226(m)(1) All.

V 98.226(m)(3) All.

V 98.226(m)(4) All.

V 98.226(m)(5) All.

V 98.226(m)(6) All.

V 98.226(p) All.

X 98.246(a)(4) Only monthly volume values, 

monthly mass values, monthly 

carbon content values, 

molecular weights for gaseous 

feedstocks, molecular weights 

for gaseous products, and 
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indication of whether the 

alternative method in 

§98.243(c)(4) was used.

X 98.246(b)(5)(iii) All.

X 98.246(b)(5)(iv) All.

Y 98.256(e)(6) Only molar volume conversion 

factor for each flare.

Y 98.256(e)(7) Only molar volume conversion 

factor for each flare.

Y 98.256(e)(7)(ii) All.

Y 98.256(e)(9) Only annual volume of flare gas 

combusted, annual average 

higher heating value of the 

flare gas, volume of gas 

flared, average molecular 

weight, carbon content of the 

flare, and molar volume 

conversion factor if using Eq. 

Y–3.

Y 98.256(e)(10) Only fraction of carbon in the 

flare gas contributed by

methane.

Y 98.256(f)(7) Only molar volume conversion 

factor.

Y 98.256(f)(10) Only coke burn-off factor, 

annual throughput of unit, and 

average carbon content of coke.

Y 98.256(f)(11) Only units of measure for the 

unit-specific CH4emission 

factor, activity data for 

calculating emissions, and 

unit-specific emission factor 

for CH4.

Y 98.256(f)(12) Only unit-specific emission 
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factor for N2O, units of measure 

for the unit-specific N2O 

emission factor, and activity 

data for calculating emissions.

Y 98.256(f)(13) Only average coke burn-off 

quantity per cycle or 

measurement period, and average 

carbon content of coke.

Y 98.256(h)(4) All.

Y 98.256(h)(5) Only value of the correction, 

annual volume of recycled tail 

gas, and annual average mole 

fraction of carbon in the tail 

gas (if used to calculate 

recycling correction factor).

Y 98.256(i)(5) Only annual mass of green coke 

fed, carbon content of green 

coke fed, annual mass of 

marketable coke produced, 

carbon content of marketable 

coke produced, and annual mass 

of coke dust removed from the 

process.

Y 98.256(i)(7) Only the unit-specific 

CH4emission factor, units of 

measure for unit-specific 

CH4emission factor, and activity 

data for calculating emissions.

Y 98.256(i)(8) Only units of measure for the 

unit-specific factor, activity 

data used for calculating 

emissions, and site-specific 

emissions factor.

Y 98.256(j)(2) All.

Y 98.256(j)(5) Only CO2emission factor.
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Y 98.256(j)(6) Only CH4emission factor.

Y 98.256(j)(7) Only carbon emission factor.

Y 98.256(j)(8) Only CO2emission factor and 

carbon emission factor.

Y 98.256(j)(9) Only CH4emission factor.

Y 98.256(k)(3) Only dimensions of coke drum or 

vessel, typical gauge pressure 

of the coking drum, typical 

void fraction of coke drum or 

vessel, annual number of cokecutting cycles of coke drum or 

vessel, and molar volume 

conversion factor for each coke 

drum or vessel.

Y 98.256(k)(4) Only height and diameter of the 

coke drums, cumulative number 

of vessel openings for all 

delayed coking drums, typical 

venting pressure, void 

fraction, mole fraction of 

methane in coking gas.

Y 98.256(l)(5) Only molar volume conversion 

factor.

Y 98.256(m)(3) Only total quantity of crude 

oil plus the quantity of 

intermediate products received 

from off-site, CH4emission 

factor used, and molar volume 

conversion factor.

Y 98.256(n)(3) All (if used in Equation Y–21 

to calculate emissions from 

equipment leaks).

Y 98.256(o)(2)(ii) All.

Y 98.256(o)(4)(ii) All.
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Y 98.256(o)(4)(iii) All.

Y 98.256(o)(4)(iv) All.

Y 98.256(o)(4)(v) All.

Y 98.256(o)(4)(vi) Only tank-specific methane 

composition data and gas 

generation rate data.

Y 98.256(p)(2) Only quantity of materials 

loaded that have an equilibrium 

vapor-phase concentration of 

CH4of 0.5 volume percent or 

greater.

Z 98.266(f)(5) All.

Z 98.266(f)(6) All.

AA 98.276(b) All.

AA 98.276(c) Only annual mass of the spent 

liquor solids combusted.

AA 98.276(d) All.

AA 98.276(e) All.

AA 98.276(f) All.

AA 98.276(g) All.

AA 98.276(h) All.

AA 98.276(i) All.

BB 98.286(b)(1) All.

BB 98.286(b)(4) All.

BB 98.286(b)(6) All.

CC 98.296(b)(5) Only monthly consumption of 

trona or liquid alkaline 

feedstock (for facilities using 

Equation CC–1).
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rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 188 of 520

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CC 98.296(b)(6) Only monthly production of soda 

ash for each manufacturing line 

(for facilities using Equation 

CC–2).

CC 98.296(b)(7) All.

CC 98.296(b)(10)(i) All.

CC 98.296(b)(10)(ii) All.

CC 98.296(b)(10)(iii) All.

CC 98.296(b)(10)(iv) All.

CC 98.296(b)(10)(v) All.

CC 98.296(b)(10)(vi) All.

CC 98.296(b)(10)(vii) All.

EE 98.316(b)(6) All.

EE 98.316(b)(9) All.

GG 98.336(b)(6) All.

GG 98.336(b)(7) All.

GG 98.336(b)(10) All.

HH 98.346(a) Only year in which landfill 

first accepted waste, last year 

the landfill accepted waste, 

capacity of the landfill, and 

waste disposal quantity for 

each year of landfilling.

HH 98.346(b) Only quantity of waste 

determined using the methods in 

§98.343(a)(3)(i), quantity of 

waste determined using the 

methods in §98.343(a)(3)(ii), 

population served by the 

landfill for each year, and the 

value of landfill capacity 

(LFC) used in the calculation.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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HH 98.346(c) All.

HH 98.346(d)(1) Only degradable organic carbon 

(DOC) value, methane correction 

factor (MCF) values, and 

fraction of DOC dissimilated 

(DOCF) values.

HH 98.346(d)(2) All.

HH 98.346(e) Only fraction of CH4in landfill 

gas.

HH 98.346(f) Only surface area associated 

with each cover type.

HH 98.346(g) All.

HH 98.346(i)(5) Only annual operating hours for 

the primary destruction device, 

annual operating hours for the 

backup destruction device, 

destruction efficiency for the 

primary destruction device, and 

destruction efficiency for the 

backup destruction device.

HH 98.346(i)(6) All.

HH 98.346(i)(7) Only surface area specified in 

Table HH–3, estimated gas 

collection system efficiency, 

and annual operating hours of 

the gas collection system.

HH 98.346(i)(9) Only CH4generation value.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Subpart W—Petroleum and Natural Gas Systems

§98.230 Definition of the source category. 

(a) This source category consists of the following 

industry segments:

(1) Offshore petroleum and natural gas production. 

Offshore petroleum and natural gas production is any 

platform structure, affixed temporarily or permanently to 

offshore submerged lands, that houses equipment to extract 

hydrocarbons from the ocean or lake floor and that 

processes and/or transfers such hydrocarbons to storage, 

transport vessels, or onshore. In addition, offshore 

production includes secondary platform structures connected 

to the platform structure via walkways, storage tanks 

associated with the platform structure and floating 

production and storage offloading equipment (FPSO). This 

source category does not include reporting of emissions 

from offshore drilling and exploration that is not 

conducted on production platforms.

(2) Onshore petroleum and natural gas production. 

Onshore petroleum and natural gas production means all 

equipment on a well pad or associated with a well pad
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(including compressors, generators, or storage facilities), 

and portable non-self-propelled equipment on a well pad or 

associated with a well pad (including well drilling and 

completion equipment, workover equipment, gravity 

separation equipment, auxiliary non-transportation-related 

equipment, and leased, rented or contracted equipment) used 

in the production, extraction, recovery, lifting, 

stabilization, separation or treating of petroleum and/or 

natural gas (including condensate). This equipment also 

includes associated storage or measurement vessels and all 

enhanced oil recovery (EOR) operations using CO2, and all 

petroleum and natural gas production located on islands, 

artificial islands, or structures connected by a causeway 

to land, an island, or artificial island. 

(3) Onshore natural gas processing. Natural gas 

processing separates and recovers natural gas liquids 

(NGLs) and/or other non-methane gases and liquids from a 

stream of produced natural gas using equipment performing 

one or more of the following processes: oil and condensate 

removal, water removal, separation of natural gas liquids, 

sulfur and carbon dioxide removal, fractionation of NGLs, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 192 of 520

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or other processes, and also the capture of CO2 separated 

from natural gas streams. This segment also includes all 

residue gas compression equipment owned or operated by the 

natural gas processing facility, whether inside or outside 

the processing facility fence. This source category does 

not include reporting of emissions from gathering lines and 

boosting stations. This source category includes:

(i) All processing facilities that fractionate.

(ii) All processing facilities that do not 

fractionate with annual average throughput of 25 MMscf per 

day or greater. 

(4) Onshore natural gas transmission compression. 

Onshore natural gas transmission compression means any 

stationary combination of compressors that move natural gas 

at elevated pressure from production fields or natural gas 

processing facilities in transmission pipelines to natural 

gas distribution pipelines or into storage. In addition, 

transmission compressor station may include equipment for 

liquids separation, natural gas dehydration, and tanks for 

the storage of water and hydrocarbon liquids. Residue 

(sales) gas compression operated by natural gas processing 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 193 of 520

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facilities are included in the onshore natural gas 

processing segment and are excluded from this segment. 

This source category also does not include reporting of 

emissions from gathering lines and boosting stations –

these sources are currently not covered by subpart W.

(5) Underground natural gas storage. Underground 

natural gas storage means subsurface storage, including 

depleted gas or oil reservoirs and salt dome caverns that 

store natural gas that has been transferred from its 

original location for the primary purpose of load balancing 

(the process of equalizing the receipt and delivery of 

natural gas); natural gas underground storage processes and 

operations (including compression, dehydration and flow 

measurement, and excluding transmission pipelines); and all 

the wellheads connected to the compression units located at 

the facility that inject and recover natural gas into and 

from the underground reservoirs.

(6) Liquefied natural gas (LNG) storage. LNG storage 

means onshore LNG storage vessels located above ground, 

equipment for liquefying natural gas, compressors to 

capture and re-liquefy boil-off-gas, re-condensers, and 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 194 of 520

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vaporization units for re-gasification of the liquefied 

natural gas.

(7) LNG import and export equipment. LNG import 

equipment means all onshore or offshore equipment that 

receives imported LNG via ocean transport, stores LNG, regasifies LNG, and delivers re-gasified natural gas to a 

natural gas transmission or distribution system. LNG 

export equipment means all onshore or offshore equipment 

that receives natural gas, liquefies natural gas, stores 

LNG, and transfers the LNG via ocean transportation to any 

location, including locations in the United States.

(8) Natural gas distribution. Natural gas 

distribution means the distribution pipelines (not 

interstate transmission pipelines or intrastate 

transmission pipelines) and metering and regulating 

equipment at city gate stations, and excluding customer 

meters, that physically deliver natural gas to end users 

and is operated by a Local Distribution Company (LDC) that 

is regulated as a separate operating company by a public 

utility commission or that is operated as an independent 

municipally-owned distribution system. This segment 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 195 of 520

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excludes customer meters and infrastructure and pipelines 

(both interstate and intrastate) delivering natural gas 

directly to major industrial users and "farm taps" upstream 

of the local distribution company inlet.

(b) [Reserved]

§98.231 Reporting threshold.

(a) You must report GHG emissions under this subpart 

if your facility contains petroleum and natural gas systems 

and the facility meets the requirements of §98.2(a)(2). 

Facilities must report emissions from the onshore petroleum 

and natural gas production industry segment only if 

emission sources specified in paragraph §98.232(c) emit 

25,000 metric tons of CO2 equivalent or more per year. 

Facilities must report emissions from the natural gas 

distribution industry segment only if emission sources 

specified in paragraph §98.232(i) emit 25,000 metric tons 

of CO2 equivalent or more per year.

(b) For applying the threshold defined in 

§98.2(a)(2), natural gas processing facilities must also 

include owned or operated residue gas compression 

equipment.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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§98.232 GHGs to report. 

(a) You must report CO2, CH4, and N2O emissions from 

each industry segment specified in paragraph (b) through 

(i) of this section, CO2, CH4, and N2O emissions from each 

flare as specified in paragraph (j) of this section, and 

stationary and portable combustion emissions as applicable 

as specified in paragraph (k) of this section.

(b) For offshore petroleum and natural gas 

production, report CO2, CH4, and N2O emissions from equipment 

leaks, vented emission, and flare emission source types as 

identified in the data collection and emissions estimation 

study conducted by BOEMRE in compliance with 30 CFR 250.302 

through 304. Offshore platforms do not need to report 

portable emissions. 

(c) For an onshore petroleum and natural gas 

production facility, report CO2, CH4, and N2O emissions from 

only the following source types on a well pad or associated 

with a well pad:

(1) Natural gas pneumatic device venting.

(2) [Reserved]
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(3) Natural gas driven pneumatic pump venting.

(4) Well venting for liquids unloading.

(5) Gas well venting during well completions without 

hydraulic fracturing.

(6) Gas well venting during well completions with 

hydraulic fracturing.

(7) Gas well venting during well workovers without 

hydraulic fracturing.

(8) Gas well venting during well workovers with 

hydraulic fracturing.

(9) Flare stack emissions.

(10) Storage tanks vented emissions from produced 

hydrocarbons.

(11) Reciprocating compressor rod packing venting.

(12) Well testing venting and flaring.

(13) Associated gas venting and flaring from produced 

hydrocarbons.

(14) Dehydrator vents.

(15) [Reserved]

(16) EOR injection pump blowdown.

(17) Acid gas removal vents.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(18) EOR hydrocarbon liquids dissolved CO2.

(19) Centrifugal compressor venting.

(20) [Reserved]

(21) Equipment leaks from valves, connectors, open 

ended lines, pressure relief valves, pumps, flanges, and 

other equipment leak sources (such as instruments, loading 

arms, stuffing boxes, compressor seals, dump lever arms, 

and breather caps).

(22) You must use the methods in §98.233(z) and 

report under this subpart the emissions of CO2, CH4, and N2O 

from stationary or portable fuel combustion equipment that 

cannot move on roadways under its own power and drive 

train, and that are located at an onshore production well 

pad. Stationary or portable equipment are the following 

equipment which are integral to the extraction, processing 

or movement of oil or natural gas: well drilling and 

completion equipment, workover equipment, natural gas 

dehydrators, natural gas compressors, electrical 

generators, steam boilers, and process heaters. 

(d) For onshore natural gas processing, report CO2, 

CH4, and N2O emissions from the following sources:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 199 of 520

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(1) Reciprocating compressor rod packing venting.

(2) Centrifugal compressor venting.

(3) Blowdown vent stacks.

(4) Dehydrator vents.

(5) Acid gas removal vents.

(6) Flare stack emissions.

(7) Equipment leaks from valves, connectors, open 

ended lines, pressure relief valves, and meters. 

(e) For onshore natural gas transmission compression, 

report CO2 and CH4 emissions from the following sources:

(1) Reciprocating compressor rod packing venting.

(2) Centrifugal compressor venting.

(3) Transmission storage tanks.

(4) Blowdown vent stacks.

(5) Natural gas pneumatic device venting.

(6) [Reserved]

(7) Equipment leaks from valves, connectors, open 

ended lines, pressure relief valves, and meters. 

(f) For underground natural gas storage, report CO2

and CH4 emissions from the following sources:

(1) Reciprocating compressor rod packing venting.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(2) Centrifugal compressor venting.

(3) Natural gas pneumatic device venting.

(4) [Reserved]

(5) Equipment leaks from valves, connectors, open 

ended lines, pressure relief valves, and meters. 

(g) For LNG storage, report CO2 and CH4 emissions from 

the following sources:

(1) Reciprocating compressor rod packing venting.

(2) Centrifugal compressor venting.

(3) Equipment leaks from valves; pump seals; 

connectors; vapor recovery compressors, and other equipment 

leak sources.

(h) LNG import and export equipment, report CO2 and 

CH4 emissions from the following sources: 

(1) Reciprocating compressor rod packing venting.

(2) Centrifugal compressor venting.

(3) Blowdown vent stacks.

(4) Equipment leaks from valves, pump seals, 

connectors, vapor recovery compressors, and other equipment 

leak sources.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 201 of 520

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(i) For natural gas distribution, report CO2, and CH4, 

emissions from the following sources: 

(1) Above ground meters and regulators at custody 

transfer city gate stations, including equipment leaks 

from connectors, block valves, control valves, pressure 

relief valves, orifice meters, regulators, and open ended 

lines. Customer meters are excluded.

(2) Above ground meters and regulators at non-custody 

transfer city gate stations, including station equipment 

leaks. Customer meters are excluded.

(3) Below ground meters and regulators and vault 

equipment leaks. Customer meters are excluded.

(4) Pipeline main equipment leaks.

(5) Service line equipment leaks.

(6) Report under subpart W of this part the emissions 

of CO2, CH4, and N2O emissions from stationary fuel 

combustion sources following the methods in §98.233(z).

(j) All applicable industry segments must report the 

CO2, CH4, and N2O emissions from each flare. 

(k) Report under subpart C of this part (General 

Stationary Fuel Combustion Sources) the emissions of CO2, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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CH4, and N2O from each stationary fuel combustion unit by 

following the requirements of subpart C. Onshore petroleum 

and natural gas production facilities must report 

stationary and portable combustion emissions as specified 

in paragraph (c) of this section. Natural gas distribution 

facilities must report stationary combustion emissions as 

specified in paragraph (i) of this section. 

(l) You must report under subpart PP of this part 

(Suppliers of Carbon Dioxide), CO2 emissions captured and 

transferred off site by following the requirements of 

subpart PP.

§98.233 Calculating GHG emissions. You must calculate and 

report the annual GHG emissions as prescribed in this 

section. For actual conditions, reporters must use average 

atmospheric conditions or typical operating conditions as 

applicable to the respective monitoring methods in this 

section.

(a) Natural gas pneumatic device venting. Calculate 

CH4 and CO2 emissions from continuous high bleed, continuous 

low bleed, and intermittent bleed natural gas pneumatic 

devices using Equation W-1 of this section. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Masss,i  Count * EF * GHGi*Convi* 24*365 (Eq. W-1)

Where:

Masss,i = Annual total mass GHG emissions in metric tons 

CO2e per year at standard conditions from a 

natural gas pneumatic device vent, for GHG i.

Count = Total number of continuous high bleed, 

continuous low bleed, or intermittent bleed 

natural gas pneumatic devices of each type as 

determined in paragraph (a)(1) of this 

section.

EF = Population emission factors for natural gas 

pneumatic device venting listed in Tables W1A, W-3, and W-4 of this subpart for onshore 

petroleum and natural gas production, onshore 

natural gas transmission compression, and 

underground natural gas storage facilities, 

respectively.

GHGi = For onshore petroleum and natural gas 

production facilities, concentration of GHG i, 

CH4 or CO2, in produced natural gas as defined 

in paragraph (u)(2)(i) of this section; for 

facilities listed in §98.230(a)(4) and (a)(5), 

GHGi equals 0.952 for CH4 and 1×10-2 for CO2.

Convi = Conversion from standard cubic feet to metric 

tons CO2e; 0.000410 for CH4, and 0.00005357 for 

CO2.

24 * 365 = Conversion to yearly emissions estimate.

(1) For onshore petroleum and natural gas production, 

provide the total number of continuous high bleed, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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continuous low bleed, or intermittent bleed natural gas 

pneumatic devices of each type as follows:

(i) In the first calendar year, for the total number 

of each type, you may count the total of each type, or 

count any percentage number of each type plus an 

engineering estimate based on best available data of the 

number not counted.

(ii) In the second consecutive year, for the total 

number of each type, you may count the total of each type, 

or count any percentage number of each type plus an 

engineering estimate based on best available data of the 

number not counted.

(iii) In the third consecutive calendar year, 

complete the count of all pneumatic devices, including any 

changes to equipment counted in prior years. 

(iv) For the calendar year immediately following the 

third consecutive calendar year, and for calendar years 

thereafter, facilities must update the total count of 

pneumatic devices and adjust accordingly to reflect any 

modifications due to changes in equipment.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(2) For onshore natural gas transmission compression 

and underground natural gas storage, all natural gas 

pneumatic devices must be counted in the first year and 

updated every calendar year.

(b) [Reserved]

(c) Natural gas driven pneumatic pump venting. 

Calculate CH4 and CO2 emissions from natural gas driven 

pneumatic pump venting using Equation W-2 of this section. 

Natural gas driven pneumatic pumps covered in paragraph (e)

of this section do not have to report emissions under 

paragraph (c) of this section. 

Masss,i  Count * EF * GHGi*Convi* 24*365 (Eq. W-2)

Where:

Masss,i = Annual total mass GHG emissions in metric tons 

CO2e per year at standard conditions from all 

natural gas pneumatic pump venting, for GHG i.

Count = Total number of natural gas pneumatic pumps.

EF = Population emission factors for natural gas 

pneumatic pump venting listed in Tables W-1A 

of this subpart for onshore petroleum and 

natural gas production.

GHGi = Concentration of GHG i, CH4 or CO2, in produced 

natural gas as defined in paragraph (u)(2)(i) 

of this section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Convi = Conversion from standard cubic feet to metric 

tons CO2e; 0.000410 for CH4, and 0.00005357 for 

CO2.

24 * 365 = Conversion to yearly emissions estimate.

(d) Acid gas removal (AGR) vents. For AGR vent 

(including processes such as amine, membrane, molecular 

sieve or other absorbents and adsorbents), calculate 

emissions for CO2 only (not CH4) vented directly to the 

atmosphere or through a flare, engine (e.g. permeate from a 

membrane or de-adsorbed gas from a pressure swing adsorber 

used as fuel supplement), or sulfur recovery plant using 

any of the calculation methodologies described in paragraph 

(d) of this section.

(1) Calculation Methodology 1. If you operate and 

maintain a CEMS that measures CO2 emissions according to 

subpart C of this part, you must calculate CO2 emissions 

under this subpart by following the Tier 4 Calculation 

Methodology and all associated requirements for Tier 4 in 

subpart C of this part (General Stationary Fuel Combustion 

Sources). If CEMS and/or volumetric flow rate monitor are 

not available, you may install a CEMS that complies with 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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the Tier 4 Calculation Methodology in subpart C of this 

part (General Stationary Fuel Combustion).

(2) Calculation Methodology 2. If CEMS is not 

available but a vent meter is installed, use the CO2

composition and annual volume of vent gas to calculate 

emissions using Equation W-3 of this section.

Ea,CO2 = VS * VolCO2 (Eq. W-3)

Where:

Ea,CO2 = Annual volumetric CO2 emissions at actual 

conditions, in cubic feet per year.

VS = Total annual volume of vent gas flowing out of 

the AGR unit in cubic feet per year at actual 

conditions as determined by flow meter using 

methods set forth in §98.234(b).

VolCO2 = Volume fraction of CO2 content in vent gas out 

of the AGR unit as determined in (d)(6) of 

this section.

(3) Calculation Methodology 3. If using CEMS or a 

vent meter is not an available, you may use the inlet or 

outlet gas flow rate of the acid gas removal unit to 

calculate emissions for CO2 using Equation W-4 of this 

section.

      Ea,CO2  V   * V * Vol I VolO

* Vol I VolO (Eq. W-4)
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 208 of 520

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Where:

Ea,CO2 = Annual volumetric CO2 emissions at actual 

condition, in cubic feet per year.

V = Total annual volume of natural gas flow into 

or out of the AGR unit in cubic feet per year 

at actual condition as determined using 

methods specified in paragraph (d)(5) of this 

section.

α = Factor is 1 if the outlet stream flow is 

measured. Factor is 0 if the inlet stream 

flow is measured.

VolI = Volume fraction of CO2 content in natural gas 

into the AGR unit as determined in paragraph 

(d)(7) of this section.

VolO = Volume fraction of CO2 content in natural gas 

out of the AGR unit as determined in paragraph 

(d)(8) of this section.

(4) Calculation Methodology 4. If CEMS or a vent 

meter is not installed, you may calculate emissions using 

any standard simulation software packages, such as 

AspenTech HYSYS® and API 4679 AMINECalc, that uses the PengRobinson equation of state, and speciates CO2 emissions. A 

minimum of the following determined for typical operating 

conditions over the calendar year by engineering estimate 

and process knowledge based on best available data must be 

used to characterize emissions:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(i) Natural gas feed temperature, pressure, and flow 

rate.

(ii) Acid gas content of feed natural gas.

(iii) Acid gas content of outlet natural gas.

(iv) Unit operating hours, excluding downtime for 

maintenance or standby.

(v) Exit temperature of natural gas.

(vi) Solvent pressure, temperature, circulation rate, 

and weight.

(5) Record the gas flow rate of the inlet and outlet 

natural gas stream of an AGR unit using a meter according 

to methods set forth in §98.234(b). If you do not have a 

continuous flow meter, either install a continuous flow 

meter or use an engineering calculation to determine the 

flow rate.

(6) If continuous gas analyzer is not available on 

the vent stack, either install a continuous gas analyzer or 

take quarterly gas samples from the vent gas stream to 

determine VolCO2 according to methods set forth in 

§98.234(b).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 210 of 520

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(7) If a continuous gas analyzer is installed on the 

inlet gas stream, then the continuous gas analyzer results 

must be used. If continuous gas analyzer is not available, 

either install a continuous gas analyzer or take quarterly 

gas samples from the inlet gas stream to determine VolI 

according to methods set forth in §98.234(b).

(8) Determine volume fraction of CO2 content in 

natural gas out of the AGR unit using one of the methods 

specified in paragraph (d)(8) of this section. 

(i) If a continuous gas analyzer is installed on the 

outlet gas stream, then the continuous gas analyzer results 

must be used. If a continuous gas analyzer is not 

available, you may install a continuous gas analyzer. 

(ii) If a continuous gas analyzer is not available or 

installed, quarterly gas samples may be taken from the 

outlet gas stream to determine VolO according to methods set 

forth in §98.234(b).

(iii) Use sales line quality specification for CO2 in 

natural gas.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(9) Calculate CO2 volumetric emissions at standard 

conditions using calculations in paragraph (t) of this 

section.

(10) Mass CO2 emissions shall be calculated from 

volumetric CO2 emissions using calculations in paragraph (v) 

of this section.

(11) Determine if emissions from the AGR unit are 

recovered and transferred outside the facility. Adjust the 

emission estimated in paragraphs (d)(1) through (d)(10) of 

this section downward by the magnitude of emission 

recovered and transferred outside the facility.

(e) Dehydrator vents. For dehydrator vents, 

calculate annual CH4, CO2 and N2O (when flared) emissions 

using any of the calculation methodologies described in 

paragraph (e) of this section.

(1) Calculation Methodology 1. Calculate annual mass 

emissions from dehydrator vents with annual average daily 

throughput greater than or equal to 0.4 million standard 

cubic feet per day using a software program, such as 

AspenTech HYSYS® or GRI-GLYCalc, that uses the PengRobinson equation of state to calculate the equilibrium 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 212 of 520

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coefficient, speciates CH4 and CO2 emissions from 

dehydrators, and has provisions to include regenerator 

control devices, a separator flash tank, stripping gas and 

a gas injection pump or gas assist pump. A minimum of the 

following parameters determined by engineering estimate 

based on best available data must be used to characterize 

emissions from dehydrators:

(i) Feed natural gas flow rate.

(ii) Feed natural gas water content.

(iii) Outlet natural gas water content.

(iv) Absorbent circulation pump type (natural gas 

pneumatic/ air pneumatic/ electric). 

(v) Absorbent circulation rate.

(vi) Absorbent type: including triethylene glycol 

(TEG), diethylene glycol (DEG) or ethylene glycol (EG).

(vii) Use of stripping natural gas.

(viii) Use of flash tank separator (and disposition 

of recovered gas).

(ix) Hours operated.

(x) Wet natural gas temperature and pressure.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(xi) Wet natural gas composition. Determine this 

parameter by selecting one of the methods described under 

paragraph (e)(1)(xi)of this section.

(A) Use the wet natural gas composition as defined in 

paragraph (u)(2)(i)or (u)(2)(ii) of this section.

(B) If wet natural gas composition cannot be 

determined using paragraph (u)(2)(i) or (u)(2)(ii) of this 

section, select a representative analysis.

(C) You may use an appropriate standard method 

published by a consensus-based standards organization if 

such a method exists or you may use an industry standard 

practice as specified in §98.234(b) to sample and analyze 

wet natural gas composition.

(D) If only composition data for dry natural gas is 

available, assume the wet natural gas is saturated. 

(2) Calculation Methodology 2. Calculate annual CH4

and CO2 emissions from glycol dehydrators with annual 

average daily throughput less than 0.4 million cubic feet 

per day using Equation W-5 of this section:

Es,i EFi*Count*1000 (Eq. W-5)
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 214 of 520

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Where:

Es,i = Annual total volumetric GHG emissions (either 

CO2 or CH4) at standard conditions in cubic 

feet.

EFi = Population emission factors for glycol 

dehydrators in thousand standard cubic feet 

per dehydrator per year. Use 74.5 for CH4 and 

3.26 for CO2 at 68°F and 14.7 psia or 73.4 for 

CH4 and 3.21 for CO2 at 60°F and 14.7 psia. 

Count = Total number of glycol dehydrators with 

throughput less than 0.4 million cubic feet. 

1000 = Conversion of EFi in thousand standard cubic to 

cubic feet. 

(3) Determine if dehydrator unit has vapor recovery. 

Adjust the emissions estimated in paragraphs (e)(1) or 

(e)(2) of this section downward by the magnitude of 

emissions captured.

(4) Calculate annual emissions from dehydrator vents 

to flares or regenerator fire-box/fire tubes as follows:

(A) Use the dehydrator vent volume and gas 

composition as determined in paragraphs (e)(1) and (e)(2) 

of this section.

(B) Use the calculation methodology of flare stacks 

in paragraph (n) of this section to determine dehydrator 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 215 of 520

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vent emissions from the flare or regenerator combustion gas 

vent.

(5) Dehydrators that use desiccant shall calculate 

emissions from the amount of gas vented from the vessel 

every time it is depressurized for the desiccant refilling 

process using Equation W-6 of this section. Desiccant 

dehydrators covered in (e)(5) of this section do not have 

to report emissions under (i) of this section. 

Es,n = (H*D2*P*P2*%G*365days/yr) (Eq. W-6)

 (4*P1*T*1,000cf/Mcf*100)

Where:

Es,n = Annual natural gas emissions at standard 

conditions in cubic feet. 

H = Height of the dehydrator vessel (ft). 

D = Inside diameter of the vessel (ft). 

P1 = Atmospheric pressure (psia). 

P2 = Pressure of the gas (psia). 

P = pi (3.14).

%G = Percent of packed vessel volume that is gas. 

T = Time between refilling (days).

100 = Conversion of %G to fraction.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 216 of 520

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(6) Both CH4 and CO2 volumetric and mass emissions 

shall be calculated from volumetric natural gas emissions 

using calculations in paragraphs (u) and (v) of this 

section.

(f) Well venting for liquids unloadings. Calculate 

CO2 and CH4 emissions from well venting for liquids 

unloading using one of the calculation methodologies 

described in paragraphs (f)(1), (f)(2) or (f)(3) of this 

section. 

(1) Calculation Methodology 1. For one well of each 

unique well tubing diameter and producing horizon/formation 

combination in each gas producing field (see §98.238 for 

the definition of Field) where gas wells are vented to the 

atmosphere to expel liquids accumulated in the tubing, a 

recording flow meter shall be installed on the vent line 

used to vent gas from the well (e.g. on the vent line off 

the wellhead separator or atmospheric storage tank) 

according to methods set forth in §98.234(b). Calculate 

emissions from well venting for liquids unloading using 

Equation W-7 of this section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 217 of 520

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 

h t

Ea,n Th,t FRh,t* (Eq. W-7)

Where: 

Ea,n = Annual natural gas emissions at actual conditions 

in cubic feet. 

Th,t = Cumulative amount of time in hours of venting 

from all wells of the same tubing diameter (t) 

and producing horizon (h)/formation combination 

during the year.

FRh,t = Average flow rate in cubic feet per hour of the 

measured well venting for the duration of the 

liquids unloading, under actual conditions as 

determined in paragraph (f)(1)(i) of this 

section.

(i) Determine the well vent average flow rate as 

specified under paragraph (f)(1)(i) of this section.

(A) The average flow rate per hour of venting is 

calculated for each unique tubing diameter and producing 

horizon/formation combination in each producing field by 

averaging the recorded flow rates for the recorded time of 

one representative well venting to the atmosphere. 

(B) This average flow rate is applied to all wells in 

the field that have the same tubing diameter and producing 

horizon/formation combination, for the number of hours of 

venting these wells.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 218 of 520

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(C) A new average flow rate is calculated every other 

calendar year for each reporting field and horizon starting 

the first calendar year of data collection. 

(ii) Calculate natural gas volumetric emissions at 

standard conditions using calculations in paragraph (t) of 

this section.

(2) Calculation Methodology 2. Calculate the total

emissions for well venting for liquids unloading using 

Equation W-8 of this section.

       











         



W V

Ea n VW CDW WDW SPW SFRW HRV,W ZV,W

3 2

, 0.37 10 1.0 (Eq. W-8)

Where:

Ea,n = Annual natural gas emissions at actual 

conditions, in cubic feet/year. 

W = Number of wells with well venting for liquids 

unloading at the facility.

0.37×10-3 = {3.14 (pi)/4}/{14.7*144} (psia converted to 

pounds per square feet).

CDW = Casing diameter for each well, in inches.

WDW = Well depth to first producing horizon for each 

well, in feet.

SPW = Shut-in pressure for each well, in pounds 

square inch atmosphere (psia).

VW = Number of vents per year per well.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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SFRW = Average sales flow rate of each gas well in 

cubic feet per hour.

HRV,W = Hours that each well was left open to the 

atmosphere during each unloading event.

1.0 = Hours for average well to blowdown casing 

volume at shut-in pressure.

ZV,W = If HRV,W is less than 1.0 then ZV,W is equal to 

0. If HRV,W is greater than or equal to 1.0 

then ZV,W is equal to 1.

(i) Calculate natural gas volumetric emissions at 

standard conditions using calculations in paragraph (t) of 

this section.

(ii) [Reserved]

(3) Calculation Methodology 3. Calculate emissions 

from each well venting to the atmosphere for liquids 

unloading with plunger lift assist using Equation W-9 of 

this section.

       











         



W V

Ea n VW CDW WDW SPW SFRW HRV,W ZV,W

3 2

, 0.37 10 1.0 (Eq. W-9)

Where:

Ea,n = Annual natural gas emissions at actual 

conditions, in cubic feet/year. 

W = Number of wells with well venting for liquids 

unloading at the facility.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 220 of 520

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0.37×10-3 = {3.14 (pi)/4}/{14.7*144} (psia converted to 

pounds per square feet).

TDW = Tubing diameter for each well, in inches.

WDW = Tubing depth to plunger bumper for each well, 

in feet.

SPW = Sales line pressure for each well, in pounds 

per square inch atmospheric (psia).

NV = Number of vents per year per well.

SFRW = Average sales flow rate of each gas well in 

cubic feet per hour.

HRV,W = Hours that each well was left open to the 

atmosphere during each unloading event.

0.5 = Hours for average well to blowdown tubing 

volume at sales line pressure.

ZV,W = If HRV,W is less than 0.5 then ZV,W is equal to 

0. If HRV,W is greater than or equal to 0.5 

then ZV,W is equal to 1.

(i) Calculate natural gas volumetric emissions at 

standard conditions using calculations in paragraph (t) of 

this section. 

(ii) [Reserved]

(4) Both CH4 and CO2 volumetric and mass emissions 

shall be calculated from volumetric natural gas emissions 

using calculations in paragraphs (u) and (v) of this 

section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(g) Gas well venting during completions and workovers 

from hydraulic fracturing. Calculate CH4, CO2 and N2O (when 

flared) annual emissions from gas well venting during 

completions involving hydraulic fracturing in wells and 

well workovers using Equation W-10 of this section. Both CH4

and CO2 volumetric and mass emissions shall be calculated 

from volumetric total gas emissions using calculations in 

paragraphs (u) and (v) of this section. 

Ea,n = (T * FR) – EnF - SG (Eq. W-10)

Where:

Ea,n = Annual volumetric total gas emissions in cubic 

feet at standard conditions from gas well venting 

during completions following hydraulic 

fracturing. 

T = Cumulative amount of time in hours of all well 

completion venting in a field during the year 

reporting.

FR = Average flow rate in cubic feet per hour, under 

actual conditions, converted to standard 

conditions, as required in paragraph (g)(1) of 

this section.

EnF = Volume of CO2 or N2 injected gas in cubic feet at 

standard conditions that was injected into the 

reservoir during an energized fracture job. If 

the fracture process did not inject gas into the 

reservoir, then EnF is 0. If injected gas is CO2

then EnF is 0.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 222 of 520

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SG = Volume of natural gas in cubic feet at standard 

conditions that was recovered into a sales 

pipeline. If no gas was recovered for sales, SG 

is 0.

(1) The average flow rate for gas well venting to the 

atmosphere or to a flare during well completions and 

workovers from hydraulic fracturing shall be determined 

using either of the calculation methodologies described in 

this paragraph (g)(1) of this section.

(i) Calculation Methodology 1. For one well 

completion in each gas producing field and for one well 

workover in each gas producing field, a recording flow 

meter (digital or analog) shall be installed on the vent 

line, ahead of a flare if used, to measure the backflow 

venting event according to methods set forth in §98.234(b). 

(A) The average flow rate in cubic feet per hour of 

venting to the atmosphere or routed to a flare is 

determined from the flow recording over the period of 

backflow venting. 

(B) The respective flow rates are applied to all well 

completions in the producing field and to all well 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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workovers in the producing field for the total number of 

hours of venting of each of these wells. 

(C) New flow rates for completions and workovers are 

measured every other calendar year for each reporting gas 

producing field and gas producing geologic horizon in each 

gas producing field starting in the first calendar year of 

data collection. 

(D) Calculate total volumetric flow rate at standard 

conditions using calculations in paragraph (t) of this 

section.

(ii) Calculation Methodology 2. For one well 

completion in each gas producing field and for one well 

workover in each gas producing field, record the well 

flowing pressure upstream(and downstream in subsonic flow) 

of a well choke according to methods set forth in 

§98.234(b) to calculate intermittent well flow rate of gas 

during venting to the atmosphere or a flare. Calculate 

emissions using Equation W-11 of this section for subsonic 

flow or Equation W-12 of this section for sonic flow:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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































 















 

1.758

1

2

1.515

1

5 2

1.27 10 * * 3430* *

P

P

P

P

FR A Tu

(Eq. W-11)

Where:

FR = Average flow rate in cubic feet per hour, 

under subsonic flow conditions.

A = Cross sectional area of orifice (m2).

P1 = Upstream pressure (psia).

Tu = Upstream temperature (degrees Kelvin).

P2 = Downstream pressure (psia).

3430 = Constant with units of m2/(sec2 * K).

1.27*105 = Conversion from m3/second to ft3/hour.

FR A 08 *Tu 1.27 10 * * 187.

5

  (Eq. W-12)

Where:

FR = Average flow rate in cubic feet per hour, 

under sonic flow conditions.

A = Cross sectional area of orifice (m2).

Tu = Upstream temperature (degrees Kelvin).

187.08 = Constant with units of m2/(sec2 * K).

1.27*105 = Conversion from m3/second to ft3/hour.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(A) The average flow rate in cubic feet per hour of 

venting across the choke is calculated for one well 

completion in each gas producing field and for one well 

workover in each gas producing field by averaging the gas 

flow rates during venting to the atmosphere or routing to a 

flare. 

(B) The respective flow rates are applied to all well 

completions in the gas producing field and to all well 

workovers in the gas producing field for the total number 

of hours of venting of each of these wells. 

(C) Flow rates for completions and workovers in each 

field shall be calculated once every two years for each 

reporting gas producing field and geologic horizon in each 

gas producing field starting in the first calendar year of 

data collection. 

(D) Calculate total volumetric flow rate at standard 

conditions using calculations in paragraph (t) of this 

section.

(2) The volume of CO2 or N2 injected into the well 

reservoir during energized hydraulic fractures will be 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 226 of 520

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measured using an appropriate meter as described in 

98.234(b) or using receipts of gas purchases that are used 

for the energized fracture job. 

(i) Calculate gas volume at standard conditions using 

calculations in paragraph (t) of this section.

(ii) [Reserved]

(3) The volume of recovered completion gas sent to a 

sales line will be measured using existing company records. 

If data does not exist on sales gas, then an appropriate 

meter as described in 98.234(b) may be used.

(i) Calculate gas volume at standard conditions using 

calculations in paragraph (t) of this section.

(ii) [Reserved]

(4) Both CH4 and CO2 volumetric and mass emissions 

shall be calculated from volumetric total emissions using 

calculations in paragraphs (u) and (v) of this section.

(5) Determine if the well completion or workover from 

hydraulic fracturing recovered gas with purpose designed 

equipment that separates saleable gas from the backflow, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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and sent this gas to a sales line (e.g. reduced emissions 

completion).

(i) Use the factor SG in Equation W-10 of this 

section, to adjust the emissions estimated in paragraphs 

(g)(1) through (g)(4) of this section by the magnitude of 

emissions captured using reduced emission completions as 

determined by engineering estimate based on best available 

data. 

(ii) [Reserved]

(6) Calculate annual emissions from gas well venting 

during well completions and workovers from hydraulic 

fracturing to flares as follows:

(i) Use the total gas well venting volume during well 

completions and workovers as determined in paragraph (g) of 

this section.

(ii) Use the calculation methodology of flare stacks 

in paragraph (n) of this section to determine gas well 

venting during well completions and workovers using 

hydraulic fracturing emissions from the flare. This

adjustment to emissions from completions using flaring 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 228 of 520

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versus completions without flaring accounts for the 

conversion of CH4 to CO2 in the flare.

(h) Gas well venting during completions and workovers 

without hydraulic fracturing. Calculate CH4, CO2 and N2O 

(when flared) emissions from each gas well venting during 

well completions and workovers not involving hydraulic 

fracturing and well workovers not involving hydraulic 

fracturing using Equation W-13 of this section:

   

f

Es,n Nwo EFwo Vf* Tf (Eq. W-13)

Where:

Es,n = Annual natural gas emissions in standard cubic 

feet from a gas well venting during well 

completions and workovers without hydraulic 

fracturing. 

Nwo = Number of workovers per field not involving 

hydraulic fracturing in the reporting year.

EFwo = Emission Factor for non-hydraulic fracture well 

workover venting in standard cubic feet per 

workover. EFwo = 3114 standard cubic feet per 

well workover without hydraulic fracturing.

f = Total number of well completions without 

hydraulic fracturing in a field.

Vf = Average daily gas production rate in standard 

cubic feet per hour of each well completion 

without hydraulic fracturing. This is the total 

annual gas production volume divided by total 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 229 of 520

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number of hours the wells produced to the sales 

line. For completed wells that have not 

established a production rate, you may use the 

average flow rate from the first 30 days of 

production. In the event that the well is 

completed less than 30 days from the end of the 

calendar year, the first 30 days of the 

production straddling the current and following 

calendar years shall be used. 

Tf = Time each well completion without hydraulic 

fracturing was venting in hours during the year.

(1) Volumetric emissions for both CH4 and CO2 shall 

be calculated from volumetric natural gas emissions using 

calculations in paragraphs (u) of this section. Mass

emissions for both CH4 and CO2 shall be calculated from 

volumetric natural gas emissions using calculations in 

paragraphs (v) of this section.

(2) Calculate annual emissions from gas well venting 

during well completions and workovers not involving 

hydraulic fracturing to flares as follows:

(i) Use the gas well venting volume during well 

completions and workovers as determined in paragraph (h) of 

this section.

(ii) Use the calculation methodology of flare stacks 

in paragraph (n) of this section to determine gas well 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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venting during well completions and workovers emissions 

without hydraulic fracturing from the flare.

(i) Blowdown vent stacks. Calculate CO2 and CH4

blowdown vent stack emissions from depressurizing equipment 

to the atmosphere (excluding depressurizing to a flare, 

over-pressure relief, operating pressure control venting 

and blowdown of non-GHG gases; desiccant dehydrator

blowdown venting before reloading is covered in paragraph 

(e)(5) of this section) as follows (Emissions from 

emergency events are not included.): 

(1) Calculate the total volume (including pipelines, 

compressor case or cylinders, manifolds, suction bottles, 

discharge bottles, and vessels) between isolation valves 

determined by engineering estimate based on best available 

data.

(2) If the total physical volume between isolation 

valves is greater than or equal to 50 cubic feet, retain 

logs of the number of blowdowns for each equipment type 

(including but not limited to compressors, vessels, 

pipelines, headers, fractionators, and tanks). Blowdown 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 231 of 520

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volumes smaller than 50 standard cubic feet are exempt from 

reporting under paragraph (i) of this section.

(3) Calculate the total annual venting emissions for 

each equipment type using Equation W-14 of this section:

 

 





































 V C

T P

T P

E N V v

a s

s a

s n v

*

459.67

459.67 * , (Eq. W-14)

Where:

Es,n = Annual natural gas venting emissions at standard 

conditions from blowdowns in cubic feet.

N = Number of repetitive blowdowns for each equipment 

type of a unique volume in calendar year.

Vv = Total physical volume of blowdown equipment 

chambers (including pipelines, compressors and 

vessels) between isolation valves in cubic feet.

C = Purge factor that is 1 if the equipment is not 

purged or zero if the equipment is purged using 

non-GHG gases.

Ts = Temperature at standard conditions (oF).

Ta = Temperature at actual conditions in the blowdown 

equipment chamber (oF).

Ps = Absolute pressure at standard conditions (psia).

Pa = Absolute pressure at actual conditions in the 

blowdown equipment chamber (psia).

(4) Calculate both CH4 and CO2 volumetric and mass 

emissions using calculations in paragraph (u) and (v) of 

this section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(5) Calculate total annual venting emissions for all 

blowdown vent stacks by adding all standard volumetric and 

mass emissions determined in Equation W-14 and paragraph 

(i)(4) of this section.

(j) Onshore production storage tanks. Calculate CH4, 

CO2 and N2O (when flared) emissions from atmospheric 

pressure fixed roof storage tanks receiving hydrocarbon 

produced liquids from onshore petroleum and natural gas 

production facilities (including stationary liquid storage 

not owned or operated by the reporter), calculate annual CH4

and CO2 emissions using any of the calculation methodologies 

described in this paragraph (j). 

(1) Calculation Methodology 1. For separators with 

annual average daily throughput of oil greater than or 

equal to 10 barrels per day. Calculate annual CH4 and CO2

emissions from onshore production storage tanks using 

operating conditions in the last wellhead gas-liquid 

separator before liquid transfer to storage tanks. 

Calculate flashing emissions with a software program, such 

as AspenTech HYSYS® or API 4697 E&P Tank, that uses the 

Peng-Robinson equation of state, models flashing emissions, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 233 of 520

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and speciates CH4 and CO2 emissions that will result when 

the oil from the separator enters an atmospheric pressure 

storage tank. A minimum of the following parameters 

determined for typical operating conditions over the year 

by engineering estimate and process knowledge based on best 

available data must be used to characterize emissions from 

liquid transferred to tanks.

(i) Separator temperature.

(ii) Separator pressure.

(iii) Sales oil or stabilized oil API gravity. 

(iv) Sales oil or stabilized oil production rate.

(v) Ambient air temperature.

(vi) Ambient air pressure.

(vii) Separator oil composition and Reid vapor 

pressure. If this data is not available, determine these 

parameters by selecting one of the methods described under 

paragraph (j)(1) (vii) of this section.

(A) If separator oil composition and Reid vapor 

pressure default data are provided with the software 

program, select the default values that most closely match 

your separator pressure first, and API gravity secondarily.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(B) If separator oil composition and Reid vapor 

pressure data are available through your previous analysis, 

select the latest available analysis that is representative 

of produced crude oil or condensate from the field. 

(C) Analyze a representative sample of separator oil 

in each field for oil composition and Reid vapor pressure 

using an appropriate standard method published by a 

consensus-based standards organization.

(2) Calculation Methodology 2. Calculate annual CH4

and CO2 emissions from onshore production storage tanks for 

wellhead gas-liquid separators with annual average daily 

throughput of oil greater than or equal to 10 barrels per 

day by assuming that all of the CH4 and CO2 in solution at 

separator temperature and pressure is emitted from oil sent 

to storage tanks. You may use an appropriate standard 

method published by a consensus-based standards 

organization if such a method exists or you may use an 

industry standard practice as described in §98.234(b) to 

sample and analyze separator oil composition at separator 

pressure and temperature.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(3) Calculation Methodology 3. For wells with annual 

average daily oil production greater than or equal to 10 

barrels per day that flow directly to atmospheric storage 

tanks without passing through a wellhead separator, 

calculate annual CH4 and CO2 emissions by either of the 

methods in paragraph (j)(3) of this section:

(i) If well production oil and gas compositions are 

available through your previous analysis, select the latest 

available analysis that is representative of produced oil 

and gas from the field and assume all of the CH4 and CO2 in 

both oil and gas are emitted from the tank.

(ii) If well production oil and gas compositions are 

not available, use default oil and gas compositions in 

software programs, such as API 4697 E&P Tank, that most 

closely match your well production gas/oil ratio and API 

gravity and assume all of the CH4 and CO2 in both oil and 

gas are emitted from the tank. 

(4) Calculation Methodology 4. For wells with annual 

average daily oil production greater than or equal to 10 

barrels per day that flow to a separator not at the well 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Page 236 of 520

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pad, calculate annual CH4 and CO2 emissions by either of the 

methods in paragraph (j)(4) of this section:

(i) If well production oil and gas compositions are 

available through your previous analysis, select the latest 

available analysis that is representative of oil at 

separator pressure determined by best available data and 

assume all of the CH4 and CO2 in the oil is emitted from the 

tank.

(ii) If well production oil composition is not 

available, use default oil composition in software 

programs, such as API 4697 E&P Tank, that most closely 

match your well production API gravity and pressure in the 

off-well pad separator determined by best available data. 

Assume all of the CH4 and CO2 in the oil phase is emitted 

from the tank.

(5) Calculation Methodology 5. For well pad gasliquid separators and for wells flowing off a well pad 

without passing through a gas-liquid separator with 

throughput less than 10 barrels per day use Equation W-15 

of this section:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Es,i EFi*Count*1000

(Eq. W-15)

Where:

Es,i = Annual total volumetric GHG emissions (either 

CO2 or CH4) at standard conditions in cubic 

feet.

EFi = Populations emission factor for separators or

wells in thousand standard cubic feet per 

separator or well per year, for crude oil use 

4.3 for CH4 and 2.9 for CO2 at 68°F and 14.7 

psia, and for gas condensate use 17.8 for CH4

and 2.9 for CO2 at 68°F and 14.7 psia.

Count = Total number of separators or wells with 

throughput less than 10 barrels per day.

1000 = Conversion to cubic feet

(6) Determine if the storage tank receiving your 

separator oil has a vapor recovery system. 

(i) Adjust the emissions estimated in paragraphs 

(j)(1) through (j)(5) of this section downward by the 

magnitude of emissions recovered using a vapor recovery 

system as determined by engineering estimate based on best 

available data.

(ii) [Reserved]

(7) Determine if the storage tank receiving your 

separator oil is sent to flare(s).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(i) Use your separator flash gas volume and gas 

composition as determined in this section.

(ii) Use the calculation methodology of flare stacks 

in paragraph (n) of this section to determine your 

contribution to storage tank emissions from the flare.

(8) Calculate emissions from occurrences of well pad 

gas-liquid separator liquid dump valves not closing during 

the calendar year by using Equation W-16 of this section.

   n n n

n

s i n T E T

E

E CF   











 * * 8760

8760

* , (Eq. W-16)

Where:

Es,i = Annual total volumetric GHG emissions at 

standard conditions from each storage tank in 

cubic feet.

En = Storage tank emissions as determined in 

Calculation Methodologies 1, 2, or 4 in 

paragraphs (j)(1), (j)(2) and (j)(4) of this 

section (with wellhead separators) in cubic feet 

per year. 

Tn = Total time the dump valve is not closing 

properly in the calendar year in hours. Tn is 

estimated by maintenance or operations records 

(records) such that when a record shows the 

valve to be open improperly, it is assumed the 

valve was open for the entire time period 

preceding the record starting at either the 

beginning of the calendar year or the previous 

record showing it closed properly within the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 239 of 520

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calendar year. If a subsequent record shows it 

is closing properly, then assume from that time 

forward the valve closed properly until either 

the next record of it not closing properly or, 

if there is no subsequent record, the end of the 

calendar year. 

CFn = Correction factor for tank emissions for time 

period Tn is 3.87 for crude oil production. 

Correction factor for tank emissions for time 

period Tn is 5.37 for gas condensate production. 

Correction factor for tank emissions for time 

period Tn is 1.0 for periods when the dump valve 

is closed.

8,760 = Conversion to hourly emissions.

(9) Calculate both CH4 and CO2 mass emissions from 

volumetric natural gas emissions using calculations in 

paragraph (v) of this section.

(k) Transmission storage tanks. For condensate 

storage tanks, either water or hydrocarbon, without vapor 

recovery or thermal control devices in onshore natural gas 

transmission compression facilities calculate CH4, CO2 and 

N2O (when flared) annual emissions from compressor scrubber 

dump valve leakage as follows: 

(1) Monitor the tank vapor vent stack annually for 

emissions using an optical gas imaging instrument according 

to methods set forth in §98.234(a)(1) for a duration of 5 

minutes. Or you may annually monitor leakage through 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 240 of 520

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compressor scrubber dump valve(s) into the tank using an 

acoustic leak detection device according to methods set 

forth in §98.234(a)(5).

(2) If the tank vapors are continuous for 5 minutes, 

or the acoustic leak detection device detects a leak, then 

use one of the following two methods in paragraph (k)(2) of 

this section to quantify annual emissions: 

(i) Use a meter, such as a turbine meter, to estimate 

tank vapor volumes according to methods set forth in 

§98.234(b). If you do not have a continuous flow 

measurement device, you may install a flow measuring device 

on the tank vapor vent stack.

(ii) Use an acoustic leak detection device on each 

scrubber dump valve connected to the tank according to the 

method set forth in §98.234(a)(5).

(iii) Use the appropriate gas composition in 

paragraph (u)(2)(iii) of this section.

(3) If the leaking dump valve(s) is fixed following 

leak detection, the annual emissions shall be calculated 

from the beginning of the calendar year to the time the 

valve(s) is repaired.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(4) Calculate annual emissions from storage tanks to 

flares as follows:

(i) Use the storage tank emissions volume and gas 

composition as determined in paragraphs (k)(1) through 

(k)(3) of this section.

(ii) Use the calculation methodology of flare stacks 

in paragraph (n) of this section to determine storage tank 

emissions sent to a flare.

(l) Well testing venting and flaring. Calculate CH4, 

CO2 and N2O (when flared) well testing venting and flaring 

emissions as follows:

(1) Determine the gas to oil ratio (GOR) of the 

hydrocarbon production from each well tested.

(2) If GOR cannot be determined from your available 

data, then you must measure quantities reported in this 

section according to one of the two procedures in 

paragraph (l)(2) of this section to determine GOR:

(i) You may use an appropriate standard method 

published by a consensus-based standards organization if 

such a method exists. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(ii) Or you may use an industry standard practice as 

described in §98.234(b).

(3) Estimate venting emissions using Equation W-17 of 

this section.

Ea,n  GOR * FR*D (Eq. W-17)

Where:

Ea,n = Annual volumetric natural gas emissions from well 

testing in cubic feet under actual conditions.

GOR = Gas to oil ratio in cubic feet of gas per barrel 

of oil; oil here refers to hydrocarbon liquids 

produced of all API gravities.

FR = Flow rate in barrels of oil per day for the well 

being tested.

D = Number of days during the year, the well is 

tested.

(4) Calculate natural gas volumetric emissions at 

standard conditions using calculations in paragraph (t) of 

this section.

(5) Calculate both CH4 and CO2 volumetric and mass 

emissions from volumetric natural gas emissions using 

calculations in paragraphs (u) and (v) of this section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(6) Calculate emissions from well testing to flares 

as follows:

(i) Use the well testing emissions volume and gas 

composition as determined in paragraphs (l)(1) through (3) 

of this section.

(ii) Use the calculation methodology of flare stacks 

in paragraph (n) of this section to determine well testing 

emissions from the flare.

(m) Associated gas venting and flaring. Calculate 

CH4, CO2 and N2O (when flared) associated gas venting and 

flaring emissions not in conjunction with well testing 

(refer to paragraph (l): Well testing venting and flaring 

of this section) as follows:

(1) Determine the GOR of the hydrocarbon production 

from each well whose associated natural gas is vented or 

flared. If GOR from each well is not available, the GOR 

from a cluster of wells in the same field shall be used. 

(2) If GOR cannot be determined from your available 

data, then use one of the two procedures in paragraph 

(m)(2) of this section to determine GOR:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(i) You may use an appropriate standard method 

published by a consensus-based standards organization if 

such a method exists.

(ii) Or you may use an industry standard practice as 

described in §98.234(b).

(3) Estimate venting emissions using Equation W-18 of 

this section.

Ea,n  GOR * V (Eq. W-18)

Where:

Ea,n = Annual volumetric natural gas emissions from 

associated gas venting under actual conditions, 

in cubic feet.

GOR = Gas to oil ratio in cubic feet of gas per barrel 

of oil; oil here refers to hydrocarbon liquids 

produced of all API gravities.

V = Volume of oil produced in barrels in the calendar 

year during which associated gas was vented or 

flared.

(4) Calculate natural gas volumetric emissions at 

standard conditions using calculations in paragraph (t) of 

this section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 245 of 520

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(5) Calculate both CH4 and CO2 volumetric and mass 

emissions from volumetric natural gas emissions using 

calculations in paragraphs (u) and (v) of this section.

(6) Calculate emissions from associated natural gas 

to flares as follows:

(i) Use the associated natural gas volume and gas 

composition as determined in paragraph (m)(1) through (4) 

of this section.

(ii) Use the calculation methodology of flare stacks 

in paragraph (n) of this section to determine associated 

gas emissions from the flare.

(n) Flare stack emissions. Calculate CO2, CH4, and 

N2O emissions from a flare stack as follows:

(1) If you have a continuous flow measurement device 

on the flare, you must use the measured flow volumes to 

calculate the flare gas emissions. If all of the flare gas 

is not measured by the existing flow measurement device, 

then the flow not measured can be estimated using 

engineering calculations based on best available data or 

company records. If you do not have a continuous flow 

measurement device on the flare, you can install a flow 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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measuring device on the flare or use engineering 

calculations based on process knowledge, company records, 

and best available data. 

(2) If you have a continuous gas composition analyzer 

on gas to the flare, you must use these compositions in 

calculating emissions. If you do not have a continuous gas 

composition analyzer on gas to the flare, you must use the 

appropriate gas compositions for each stream of 

hydrocarbons going to the flare as follows:

(i) For onshore natural gas production, determine 

natural gas composition using (u)(2)(i) of this section.

(ii) For onshore natural gas processing, when the 

stream going to flare is natural gas, use the GHG mole 

percent in feed natural gas for all streams upstream of the 

de-methanizer or dew point control, and GHG mole percent in 

facility specific residue gas to transmission pipeline 

systems for all emissions sources downstream of the demethanizer overhead or dew point control for onshore 

natural gas processing facilities.

(iii) When the stream going to the flare is a 

hydrocarbon product stream, such as ethane, propane, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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butane, pentane-plus and mixed light hydrocarbons, then use 

a representative composition from the source for the stream 

determined by engineering calculation based on process 

knowledge and best available data.

(3) Determine flare combustion efficiency from 

manufacturer. If not available, assume that flare 

combustion efficiency is 98 percent.

(4) Calculate GHG volumetric emissions at actual 

conditions using Equations W-19, W-20, and W-21 of this 

section.

  , 4 4*(1 ) * a CH Va X CH E un  combusted  

(Eq. W-19)

  , 2 2* a CO Va X CO E un  combusted 

(Eq. W-20)

   

j

a CO Va Yj Rj E , 2

combusted  * * * (Eq. W-21)

Where:

Ea,CH4(un-combusted) = Contribution of annual un-combusted 

CH4 emissions from flare stack in 

cubic feet, under actual conditions.

Ea,CO2(un-combusted) = Contribution of annual un-combusted 

CO2 emissions from flare stack in 

cubic feet, under actual conditions.

Ea,CO2(combusted) = Contribution of annual combusted CO2

emissions from flare stack in cubic 

feet, under actual conditions.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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Va = Volume of gas sent to flare in cubic 

feet, during the year.

η = Fraction of gas combusted by a 

burning flare (default is 0.98). For 

gas sent to an unlit flare, η is 

zero.

XCH4 = Mole fraction of CH4 in gas to the 

flare.

XCO2 = Mole fraction of CO2 in gas to the 

flare.

Yj = Mole fraction of gas hydrocarbon 

constituents j (such as methane, 

ethane, propane, butane, and 

pentanes-plus).

Rj = Number of carbon atoms in the gas 

hydrocarbon constituent j: 1 for 

methane, 2 for ethane, 3 for propane, 

4 for butane, and 5 for pentanes 

plus).

(5) Calculate GHG volumetric emissions at standard 

conditions using calculations in paragraph (t) of this 

section.

(6) Calculate both CH4 and CO2 mass emissions from 

volumetric CH4 and CO2 emissions using calculation in 

paragraph (v) of this section.

(7) Calculate total annual emission from flare stacks 

by summing Equation W-40, Equation W-19, Equation W-20 and 

Equation W-21 of this section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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(8) Calculate N2O emissions from flare stacks using 

Equation W-40 in paragraph (z) of this section.

(9) The flare emissions determined under paragraph 

(n) of this section must be corrected for flare emissions 

calculated and reported under other paragraphs of this 

section to avoid double counting of these emissions. 

(o) Centrifugal compressor venting. Calculate CH4, 

CO2 and N2O (when flared) emissions from both wet seal and 

dry seal centrifugal compressor vents as follows: 

(1) For each centrifugal compressor covered by 

§98.232 (d)(2), (e)(2), (f)(2), (g)(2), and (h)(2) you must 

conduct an annual measurement in the operating mode in 

which it is found. Measure emissions from all vents 

(including emissions manifolded to common vents) including 

wet seal oil degassing vents, unit isolation valve vents, 

and blowdown valve vents. Record emissions from the 

following vent types in the specified compressor modes 

during the annual measurement.

(i) Operating mode, blowdown valve leakage through 

the blowdown vent, wet seal and dry seal compressors.

(ii) Operating mode, wet seal oil degassing vents.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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(iii) Not operating, depressurized mode, unit 

isolation valve leakage through open blowdown vent, without 

blind flanges, wet seal and dry seal compressors. 

(A) For the not operating, depressurized mode, each 

compressor must be measured at least once in any three 

consecutive calendar years. If a compressor is not 

operated and has blind flanges in place throughout the 3 

year period, measurement is not required in this mode. If 

the compressor is in standby depressurized mode without 

blind flanges in place and is not operated throughout the 3 

year period, it must be measured in the standby 

depressurized mode.

(2) For wet seal oil degassing vents, determine vapor 

volumes sent to an atmospheric vent or flare, using a 

temporary meter such as a vane anemometer or permanent flow 

meter according to 98.234(b) of this section. If you do 

not have a permanent flow meter, you may install a 

permanent flow meter on the wet seal oil degassing tank 

vent.

(3) For blowdown valve leakage and unit isolation 

valve leakage to open ended vents, you can use one of the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 251 of 520

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following methods: calibrated bagging or high volume 

sampler according to methods set forth in §98.234(c) and 

§98.234(d), respectively. For through valve leakage, such 

as isolation valves, you may use an acoustic leak detection 

device according to methods set forth in §98.234(a). If 

you do not have a flow meter, you may install a port for 

insertion of a temporary meter, or a permanent flow meter, 

on the vents. 

(4) Estimate annual emissions using the flow 

measurement and Equation W-22 of this section.

* * *(1 ) Es,i,m MTm Tm Mi,m  Bm (Eq. W-22)

Where:

Es,i,m = Annual GHG i (either CH4 or CO2) volumetric 

emissions at standard conditions, in cubic feet.

MTm = Measured gas emissions in standard cubic feet per 

hour.

Tm = Total time the compressor is in the mode for 

which Es,i is being calculated, in the calendar 

year in hours.

Mi,m = Mole fraction of GHG i in the vent gas; use the 

appropriate gas compositions in paragraph (u)(2) 

of this section.

Bm = Fraction of operating time that the vent gas is 

sent to vapor recovery or fuel gas as determined 

by keeping logs of the number of operating hours 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Page 252 of 520

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for the vapor recovery system and the time that 

vent gas is directed to the fuel gas system or 

sales.

(5) Calculate annual emissions from each centrifugal 

compressor using Equation W-23 of this section.

 mEs i EFm Tm GHGi* * , (Eq. W-23)

Where:

Es,i = Annual total volumetric GHG emissions at 

standard conditions from each centrifugal 

compressor in cubic feet.

EFm = Reporter emission factor for each mode m, in 

cubic feet per hour, from Equation W-24 of this 

section as calculated in paragraph 6. 

Tm = Total time in hours per year the compressor was 

in each mode, as listed in paragraph (o)(1)(i) 

through (o)(1)(iii).

GHGi = For onshore natural gas processing facilities, 

concentration of GHG i, CH4 or CO2, in produced 

natural gas or feed natural gas; for other 

facilities listed in §98.230(a)(4) through 

(a)(8),GHGi equals 1.

(6) You shall use the flow measurements of operating 

mode wet seal oil degassing vent, operating mode blowdown 

valve vent and not operating depressurized mode isolation 

valve vent for all the reporter’s compressor modes not 

measured in the calendar year to develop the following 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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emission factors using Equation W-24 of this section for 

each emission source and mode as listed in paragraph 

(o)(1)(i) through (o)(1)(iii). 

  m

m

m

Count

MT EF (Eq. W-24)

Where:

EFm = Reporter emission factors for compressor in the 

three modes m (as listed in paragraph (o)(1)(i) 

through (o)(1)(iii)) in cubic feet per hour.

MTm = Flow Measurements from all centrifugal compressor 

vents in each mode in (o)(1)(i) through 

(o)(1)(iii) of this section in cubic feet per 

hour.

Countm = Total number of compressors measured.

m = Compressor mode as listed in paragraph (o)(1)(i) 

through (o)(1)(iii). 

(i) The emission factors must be calculated 

annually. You must use all measurements from the current 

calendar year and the preceding two calendar years, 

totaling three consecutive calendar years of measurements 

in paragraph (o)(6) of this section.

(ii) [Reserved]
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(7) Onshore petroleum and natural gas production 

shall calculate emissions from centrifugal compressor wet 

seal oil degassing vents as follows:

Es,i Count * EFi (Eq. W-25)

Where:

Es,i = Annual total volumetric GHG emissions at 

standard conditions from centrifugal compressor 

wet seals in cubic feet.

Count = Total number of centrifugal compressors for the 

reporter.

EFi = Emission factor for GHG i. Use 12.2 million 

standard cubic feet per year per compressor for 

CH4 and 538 thousand standard cubic feet per year 

per compressor for CO2 at 68°F and 14.7 psia or 

12 million standard cubic feet per year per 

compressor for CH4 and 530 thousand standard 

cubic feet per year per compressor for CO2 at 

60°F and 14.7 psia.

(8) Calculate both CH4 and CO2 mass emissions from 

volumetric emissions using calculations in paragraph (v) of 

this section.

(9) Calculate emissions from seal oil degassing vent 

vapors to flares as follows:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(i) Use the seal oil degassing vent vapor volume and 

gas composition as determined in paragraphs (o)(5) of this 

section.

(ii) Use the calculation methodology of flare stacks 

in paragraph (n) of this section to determine degassing 

vent vapor emissions from the flare.

(p) Reciprocating compressor venting. Calculate CH4

and CO2 emissions from all reciprocating compressor vents as 

follows. For each reciprocating compressor covered in 

§98.232(d)(1), (e)(1), (f)(1), (g)(1), and (h)(1) you must 

conduct an annual measurement for each compressor in the 

mode in which it is found during the annual measurement, 

except as specified in paragraph (p)(9) of this section. 

Measure emissions from (including emissions manifolded to 

common vents) reciprocating rod packing vents, unit 

isolation valve vents, and blowdown valve vents. Record 

emissions from the following vent types in the specified 

compressor modes during the annual measurement as follows: 

(1) Operating or standby pressurized mode, blowdown 

vent leakage through the blowdown vent stack.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(2) Operating mode, reciprocating rod packing 

emissions.

(3) Not operating, depressurized mode, unit isolation 

valve leakage through the blowdown vent stack, without 

blind flanges. 

(i) For the not operating, depressurized mode, each 

compressor must be measured at least once in any three 

consecutive calendar years if this mode is not found in the 

annual measurement. If a compressor is not operated and 

has blind flanges in place throughout the 3 year period, 

measurement is not required in this mode. If the 

compressor is in standby depressurized mode without blind 

flanges in place and is not operated throughout the 3 year 

period, it must be measured in the standby depressurized 

mode.

(ii) [Reserved]

(4) If reciprocating rod packing and blowdown vent 

are connected to an open-ended vent line use one of the 

following two methods to calculate emissions:

(i) Measure emissions from all vents (including 

emissions manifolded to common vents) including rod 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 257 of 520

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packing, unit isolation valves, and blowdown vents using 

either calibrated bagging or high volume sampler according 

to methods set forth in §98.234 (c) and §98.234(d), 

respectively.

(ii) Use a temporary meter such as a vane anemometer

or a permanent meter such as an orifice meter to measure 

emissions from all vents (including emissions manifolded to 

a common vent) including rod packing vents and unit 

isolation valve leakage through blowdown vents according to 

methods set forth in §98.234(b). If you do not have a 

permanent flow meter, you may install a port for insertion 

of a temporary meter or a permanent flow meter on the 

vents. For through-valve leakage to open ended vents, such 

as unit isolation valves on not operating, depressurized 

compressors and blowdown valves on pressurized compressors, 

you may use an acoustic detection device according to 

methods set forth in §98.234(a).

(5) If reciprocating rod packing is not equipped with 

a vent line use the following method to calculate 

emissions:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(i) You must use the methods described in §98.234 (a) 

to conduct annual leak detection of equipment leaks from 

the packing case into an open distance piece, or from the 

compressor crank case breather cap or other vent with a 

closed distance piece.

(ii) Measure emissions found in paragraph (p)(5)(i) 

of this section using an appropriate meter, or calibrated 

bag, or high volume sampler according to methods set forth 

in §98.234(b), (c), and (d), respectively.

(6) Estimate annual emissions using the flow measurement 

and Equation W-26 of this section.

Es,i,m MTm *Tm * Mi,m Es,i,m MTm *Tm *Mi,m (Eq. W-26)

Where:

Es,i,m = Annual GHG i (either CH4 or CO2) volumetric 

emissions at standard conditions, in cubic feet.

MTm = Measured gas emissions in standard cubic feet per 

hour.

Tm = Total time the compressor is in the mode for 

which Es,i,m is being calculated, in the calendar 

year in hours.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Mi,m = Mole fraction of GHG i in gas; use the 

appropriate gas compositions in paragraph (u)(2) of this 

section.

(7) Calculate annual emissions from each 

reciprocating compressor using Equation W-27 of this 

section.

 mEs i EFm Tm GHGi* * , (Eq. W-27)

Where:

Es,i = Annual total volumetric GHG emissions at 

standard conditions from each reciprocating 

compressor in cubic feet.

EFm = Reporter emission factor for each mode, m, in 

cubic feet per hour, from Equation W-28 of this 

section as calculated in paragraph (p)(7)(i) of 

this section. 

Tm = Total time in hours per year the compressor was 

in each mode, m, as listed in paragraph (p)(1) 

through (p)(3).

GHGi = For onshore natural gas processing facilities, 

concentration of GHG i, CH4 or CO2, in produced 

natural gas or feed natural gas; for other 

facilities listed in §98.230(a)(4) through 

(a)(8), GHGi equals 1.

m = Compressor mode as listed in paragraph (p)(1) 

through (p)(3). 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(i) You shall use the flow meter readings from 

measurements of operating and standby pressurized blowdown 

vent, operating mode vents, not operating depressurized 

isolation valve vent for all the reporter’s compressor

modes not measured in the calendar year to develop the 

following emission factors using Equation W-28 of this 

section for each mode as listed in paragraph (p)(1) through 

(p)(3). 

  m

m

m

Count

MT EF (Eq. W-28)

Where:

EFm = Reporter emission factors for compressor in the 

three modes, m, in cubic feet per hour.

MTm = Meter readings from all reciprocating compressor 

vents in each and mode, m, in cubic feet per 

hour.

Countm = Total number of compressors measured in each 

mode, m.

m = Compressor mode as listed in paragraph (p)(1) 

through (p)(3). 

(A) You must combine emissions for blowndown vents, 

measured in the operating and standby pressurized modes.

(B) The emission factors must be calculated annually. 

You must use all measurements from the current calendar 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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year and the preceding two calendar years, totaling three 

consecutive calendar years of measurements.

(ii) [Reserved]

(8) Determine if the reciprocating compressor vent 

vapors are sent to a vapor recovery system. 

(i) Adjust the emissions estimated in paragraphs 

(p)(7) of this section downward by the magnitude of 

emissions recovered using a vapor recovery system as 

determined by engineering estimate based on best available 

data.

(ii) [Reserved]

(9) Onshore petroleum and natural gas production 

shall calculate emissions from reciprocating compressors as 

follows:

Es,i Count * EFi (Eq. W-29)

Where:

Es,i = Annual total volumetric GHG emissions at 

standard conditions from reciprocating 

compressors in cubic feet.

Count = Total number of reciprocating compressors for 

the reporter.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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EFi = Emission factor for GHG i. Use 9.63 thousand 

standard cubic feet per year per compressor for 

CH4 and 0.535 thousand standard cubic feet per 

year per compressor for CO2 at 68°F and 14.7 psia

or 9.48 thousand standard cubic feet per year 

per compressor for CH4 and 0.527 thousand 

standard cubic feet per year per compressor for 

CO2. at 60°F and 14.7 psia.

(10) Estimate CH4 and CO2 volumetric and mass 

emissions from volumetric natural gas emissions using the 

calculations in paragraphs (u) and (v) of this section.

(q) Leak detection and leaker emission factors. You 

must use the methods described in §98.234(a) to conduct 

leak detection(s) of equipment leaks from all sources 

listed in §98.232(d)(7), (e)(7), (f)(5), (g)(3), (h)(4), 

and (i)(1). This paragraph (q) applies to emissions 

sources in streams with gas content greater than 10 percent 

CH4 plus CO2 by weight. Emissions sources in streams with 

gas content less than 10 percent CH4 plus CO2 by weight do 

not need to be reported. Tubing systems equal to or less 

than one half inch diameter are exempt from the 

requirements of this paragraph (q) and do not need to be 

reported. If equipment leaks are detected for sources 

listed in this paragraph (q), calculate equipment leak 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 263 of 520

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emissions per source per reporting facility using Equation 

W-30 of this section for each source with equipment leaks. 

 xEs i GHGi EFs Tx* * , (Eq. W-30)

Where:

Es,i = Annual total volumetric GHG emissions at 

standard conditions from each equipment leak 

source in cubic feet.

x = Total number of this type of emissions source 

found to be leaking during Tx.

EFs = Leaker emission factor for specific sources 

listed in Table W-2 through Table W-7 of this 

subpart.

GHGi = For onshore natural gas processing facilities, 

concentration of GHGi, CH4 or CO2, in the total 

hydrocarbon of the feed natural gas; for other 

facilities listed in §98.230(a)(4) through 

(a)(8), GHGi equals 1 for CH4 and 1.1 × 10-2 for 

CO2. 

Tx = The total time the component was found leaking 

and operational, in hours. If one leak detection 

survey is conducted, assume the component was 

leaking for the entire calendar year. If 

multiple leak detection surveys are conducted, 

assume that the component found to be leaking 

has been leaking since the previous survey or 

the beginning of the calendar year. For the last 

leak detection survey in the calendar year, 

assume that all leaking components continue to 

leak until the end of the calendar year. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 264 of 520

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(1) You must select to conduct either one leak 

detection survey in a calendar year or multiple complete 

leak detection surveys in a calendar year. The number of 

leak detection surveys selected must be conducted during 

the calendar year.

(2) Calculate GHG mass emissions in carbon dioxide 

equivalent at standard conditions using calculations in 

paragraph (v) of this section.

(3) Onshore natural gas processing facilities shall 

use the appropriate default leaker emission factors listed 

in Table W-2 of this subpart for equipment leaks detected 

from valves, connectors, open ended lines, pressure relief 

valves, and meters.

(4) Onshore natural gas transmission compression 

facilities shall use the appropriate default leaker 

emission factors listed in Table W-3 of this subpart for 

equipment leaks detected from valves, connectors, open 

ended lines, pressure relief valves, and meters. 

(5) Underground natural gas storage facilities for 

storage stations shall use the appropriate default leaker 

emission factors listed in Table W-4 of this subpart for 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 265 of 520

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equipment leaks detected from valves, connectors, open 

ended lines, pressure relief valves, and meters.

(6) LNG storage facilities shall use the appropriate 

default leaker emission factors listed in Table W-5 of this 

subpart for equipment leaks detected from valves, pump 

seals, connectors, and other.

(7) LNG import and export facilities shall use the 

appropriate default leaker emission factors listed in Table 

W-6 of this subpart for equipment leaks detected from 

valves, pump seals, connectors, and other.

(8) Natural gas distribution facilities for above 

ground meters and regulators at city gate stations at 

custody transfer, shall use the appropriate default leaker 

emission factors listed in Table W-7 of this subpart for 

equipment leak detected from connectors, block valves, 

control valves, pressure relief valves, orifice meters, 

regulators, and open ended lines.

(r) Population count and emission factors. This 

paragraph applies to emissions sources listed in §98.232 

(c)(21), (f)(5), (g)(3), (h)(4), (i)(2), (i)(3), (i)(4) and 

(i)(5), on streams with gas content greater than 10 percent 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 266 of 520

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CH4 plus CO2 by weight. Emissions sources in streams with 

gas content less than 10 percent CH4 plus CO2 by weight do 

not need to be reported. Tubing systems equal or less than 

one half inch diameter are exempt from the requirements of 

paragraph (r) of this section and do not need to be 

reported. Calculate emissions from all sources listed in 

this paragraph using Equation W-31 of this section.

Es,i Counts * EFs *GHGi*Ts (Eq. W-31)

Where:

Es,i = Annual volumetric GHG emissions at standard 

conditions from each equipment leak source in 

cubic feet.

Counts = Total number of this type of emission source at 

the facility. Average component counts are 

provided by major equipment piece in Tables W-1B 

and Table W-1C of this subpart. Use average 

component counts as appropriate for operations 

in Eastern and Western U.S., according to Table 

W-1D of this subpart.EFs= Population emission 

factor for the specific source, s listed in 

Table W-1A and Tables W-3 through Table W-7 of 

this subpart. Use appropriate population 

emission factor for operations in Eastern and 

Western U.S., according to Table W-1D of this 

subpart. EF for non-custody transfer city gate 

stations is determined in Equation W-32.

GHGi = For onshore petroleum and natural gas production 

facilities and onshore natural gas processing 

facilities, concentration of GHG i, CH4 or CO2, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 267 of 520

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in produced natural gas or feed natural gas; for 

other facilities listed in §98.230(a)(4) through 

(a)(8),GHGi equals 1 for CH4 and 1.1 × 10-2 for 

CO2.

Ts = Total time the specific source s associated with 

the equipment leak emission was operational in 

the calendar year, in hours.

(1) Calculate both CH4 and CO2 mass emissions from 

volumetric emissions using calculations in paragraph (v) of 

this section.

(2) Onshore petroleum and natural gas production 

facilities shall use the appropriate default population 

emission factors listed in Table W-1A of this subpart for 

equipment leaks from valves, connectors, open ended lines, 

pressure relief valves, pump, flanges, and other. Major 

equipment and components associated with gas wells are 

considered gas service components in reference to Table 1-A 

of this subpart and major natural gas equipment in 

reference to Table W-1B of this subpart. Major equipment 

and components associated with crude oil wells are 

considered crude service components in reference to Table 

1-A of this subpart and major crude oil equipment in 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 268 of 520

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reference to Table W-1C of this subpart. Where facilities 

conduct EOR operations the emissions factor listed in Table 

W-1A of this subpart shall be used to estimate all streams 

of gases, including recycle CO2 stream. The component count 

can be determined using either of the methodologies 

described in this paragraph (r)(2). The same methodology 

must be used for the entire calendar year.

(i) Component Count Methodology 1. For all onshore 

petroleum and natural gas production operations in the 

facility perform the following activities:

(A) Count all major equipment listed in Table W-1B 

and Table W-1C of this subpart.

(B) Multiply major equipment counts by the average 

component counts listed in Table W-1B and W-1C of this 

subpart for onshore natural gas production and onshore oil 

production, respectively. Use the appropriate factor in 

Table W-1A of this subpart for operations in Eastern and 

Western U.S. according to the mapping in Table W-1D of this 

subpart.

(ii) Component Count Methodology 2. Count each 

component individually for the facility. Use the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 269 of 520

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appropriate factor in Table W-1A of this subpart for 

operations in Eastern and Western U.S. according to the 

mapping in Table W-1D of this subpart.

(3) Underground natural gas storage facilities for 

storage wellheads shall use the appropriate default 

population emission factors listed in Table W-4 of this 

subpart for equipment leak from connectors, valves, 

pressure relief valves, and open ended lines.

(4) LNG storage facilities shall use the appropriate 

default population emission factors listed in Table W-5 of 

this subpart for equipment leak from vapor recovery 

compressors.

(5) LNG import and export facilities shall use the 

appropriate default population emission factor listed in 

Table W-6 of this subpart for equipment leak from vapor 

recovery compressors.

(6) Natural gas distribution facilities shall use the 

appropriate emission factors as described in paragraph 

(r)(6) of this section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(i) Below grade meters and regulators; mains; and 

services, shall use the appropriate default population 

emission factors listed in Table W-7 of this subpart. 

(ii) Above grade meters and regulators at city gate 

stations not at custody transfer as listed in 

§98.232(i)(2), shall use the total volumetric GHG emissions 

at standard conditions for all equipment leak sources 

calculated in paragraph (q)(8) of this section to develop 

facility emission factors using Equation W-32 of this 

section. The calculated facility emission factor from 

Equation W-32 of this section shall be used in Equation W31 of this section.

Count

E

EF s,i  (Eq. W-32)

Where:

EF = Facility emission factor for a meter at above 

grade M&R at city gate stations not at custody 

transfer in cubic feet per meter per year.

Es,i = Annual volumetric GHG emissions at standard 

condition from all equipment leak sources at all 

above grade M&R city gate stations at custody 

transfer, from paragraph (q) of this section.

Count = Total number of meter runs at all above grade M&R 

city gate stations at custody transfer.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 271 of 520

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(s) Offshore petroleum and natural gas production 

facilities. Report CO2, CH4, and N2O emissions for offshore 

petroleum and natural gas production from all equipment 

leaks, vented emission, and flare emission source types as 

identified in the data collection and emissions estimation 

study conducted by BOEMRE in compliance with 30 CFR 250.302 

through 304.

(1) Offshore production facilities under BOEMRE 

jurisdiction shall report the same annual emissions as 

calculated and reported by BOEMRE in data collection and 

emissions estimation study published by BOEMRE referenced 

in 30 CFR 250.302 through 304 (GOADS).

(i) For any calendar year that does not overlap with 

the most recent BOEMRE emissions study publication year, 

report the most recent BOEMRE reported emissions data 

published by BOEMRE referenced in 30 CFR 250.302 through 

304 (GOADS). Adjust emissions based on the operating time 

for the facility relative to the operating time in the most 

recent BOEMRE published study.

(ii) [Reserved]
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(2) Offshore production facilities that are not under 

BOEMRE jurisdiction shall use monitoring methods and 

calculation methodologies published by BOEMRE referenced in 

30 CFR 250.302 through 304 to calculate and report 

emissions (GOADS).

(i) For any calendar year that does not overlap with 

the most recent BOEMRE emissions study publication, report 

the most recent reported emissions data with emissions 

adjusted based on the operating time for the facility 

relative to operating time in the previous reporting 

period.

(ii) [Reserved]

(3) If BOEMRE discontinues or delays their data 

collection effort by more than 4 years, then offshore 

reporters shall once in every 4 years use the most recent 

BOEMRE data collection and emissions estimation methods to 

report emission from the facility sources. 

(4) For either first or subsequent year reporting, 

offshore facilities either within or outside of BOEMRE 

jurisdiction that were not covered in the previous BOEMRE 

data collection cycle shall use the most recent BOEMRE data 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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collection and emissions estimation methods published by 

BOEMRE referenced in 30 CFR 250.302 through 304 to 

calculate and report emissions (GOADS) to report emissions.

(t) Volumetric emissions. Calculate volumetric 

emissions at standard conditions as specified in paragraphs 

(t)(1) or (2) of this section determined by engineering 

estimate based on best available data unless otherwise 

specified. 

(1) Calculate natural gas volumetric emissions at 

standard conditions by converting actual temperature and 

pressure of natural gas emissions to standard temperature 

and pressure of natural gas using Equation W-33 of this 

section. 

 

  a s

a n s a

s n

T P

E T P

E

459.67 *

* 459.67 * ,

,





 (Eq. W-33)

Where:

Es,n = Natural gas volumetric emissions at standard 

temperature and pressure (STP) conditions in 

cubic feet.

Ea,n = Natural gas volumetric emissions at actual 

conditions in cubic feet.

Ts = Temperature at standard conditions (oF).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Ta = Temperature at actual emission conditions (oF).

Ps = Absolute pressure at standard conditions (psia).

Pa = Absolute pressure at actual conditions (psia).

(2) Calculate GHG volumetric emissions at standard 

conditions by converting actual temperature and pressure of 

GHG emissions to standard temperature and pressure using 

Equation W-34 of this section. 

(Eq. W-34)

Where:

Es,i = GHG i volumetric emissions at standard 

temperature and pressure (STP) conditions in 

cubic feet.

Ea,i = GHG i volumetric emissions at actual conditions 

in cubic feet.

Ts = Temperature at standard conditions (oF).

Ta = Temperature at actual emission conditions (oF).

Ps = Absolute pressure at standard conditions (psia).

Pa = Absolute pressure at actual conditions (psia).

(u) GHG volumetric emissions. Calculate GHG 

volumetric emissions at standard conditions as specified in 

 

  a s

a i s a

s i

T P

E T P

E

459 .67 *

, * 459 .67 *

,






DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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paragraphs (u)(1) and (2) of this section determined by 

engineering estimate based on best available data unless 

otherwise specified.

(1) Estimate CH4 and CO2 emissions from natural gas 

emissions using Equation W-35 of this section.

(Eq. W-35)

Where:

Es,i = GHG i (either CH4 or CO2) volumetric emissions at 

standard conditions in cubic feet.

Es,n = Natural gas volumetric emissions at standard 

conditions in cubic feet.

Mi = Mole fraction of GHG i in the natural gas. 

(2) For Equation W-35 of this section, the mole 

fraction, Mi, shall be the annual average mole fraction for 

each facility, as specified in paragraphs (u)(2)(i) through 

(vii) of this section.

(i) GHG mole fraction in produced natural gas for 

onshore petroleum and natural gas production facilities. 

If you have a continuous gas composition analyzer for 

produced natural gas, you must use these values for 

Es i Es n Mi* ,  ,
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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determining the mole fraction. If you do not have a 

continuous gas composition analyzer, then you must use your 

most recent gas composition based on available sample 

analysis of the field.

(ii) GHG mole fraction in feed natural gas for all 

emissions sources upstream of the de-methanizer or dew 

point control and GHG mole fraction in facility specific 

residue gas to transmission pipeline systems for all 

emissions sources downstream of the de-methanizer overhead 

or dew point control for onshore natural gas processing 

facilities. If you have a continuous gas composition 

analyzer on feed natural gas, you must use these values for 

determining the mole fraction. If you do not have a 

continuous gas composition analyzer, then annual samples 

must be taken according to methods set forth in §98.234(b).

(iii) GHG mole fraction in transmission pipeline 

natural gas that passes through the facility for onshore 

natural gas transmission compression facilities. 

(iv) GHG mole fraction in natural gas stored in 

underground natural gas storage facilities. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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(v) GHG mole fraction in natural gas stored in LNG 

storage facilities. 

(vi) GHG mole fraction in natural gas stored in LNG 

import and export facilities. 

(vii) GHG mole fraction in local distribution 

pipeline natural gas that passes through the facility for 

natural gas distribution facilities. 

(v) GHG mass emissions. Calculate GHG mass emissions 

in carbon dioxide equivalent at standard conditions by 

converting the GHG volumetric emissions into mass emissions 

using Equation W-36 of this section.

(Eq. W-36)

Where:

Masss,i = GHG i (either CH4 or CO2) mass emissions at 

standard conditions in metric tons CO2e. 

Es,i = GHG i (either CH4 or CO2) volumetric emissions at 

standard conditions, in cubic feet.

= Density of GHG i. Use 0.0520 kg/ft3 for CO2 and 

N2O, and 0.0190 kg/ft3 for CH4 at 68°F and 14.7 

psia or 0.0530 kg/ft3 for CO2 and N2O, and 0.0193 

kg/ft3 for CH4 at 60°F and 14.7 psia .

GWP = Global warming potential, 1 for CO2, 21 for CH4, 

and 310 for N2O.

3

, ,

* * * 10  Mass s i  Es i i GWP

 i
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(w) EOR injection pump blowdown. Calculate CO2 pump 

blowdown emissions as follows: 

(1) Calculate the total volume in cubic feet 

(including pipelines, manifolds and vessels) between 

isolation valves.

(2) Retain logs of the number of blowdowns per 

calendar year.

(3) Calculate the total annual venting emissions 

using Equation W-37 of this section:

3

, * * * *10  Mass c i N Vv Rc GHGi (Eq. W-37)

Where:

Massc,i = Annual EOR injection gas venting emissions in 

metric tons at critical conditions “c” from 

blowdowns.

N = Number of blowdowns for the equipment in the 

calendar year.

Vv = Total volume in cubic feet of blowdown equipment 

chambers (including pipelines, manifolds and 

vessels) between isolation valves.

Rc = Density of critical phase EOR injection gas in 

kg/ft3. You may use an appropriate standard 

method published by a consensus-based standards 

organization if such a method exists or you may 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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use an industry standard practice to determine 

density of super critical EOR injection gas.

GHGi = Mass fraction of GHGi in critical phase injection 

gas.

1 × 10-3 = Conversion factor from kilograms to metric tons.

(x) EOR hydrocarbon liquids dissolved CO2. Calculate 

dissolved CO2 in hydrocarbon liquids produced through EOR 

operations as follows:

(1) Determine the amount of CO2 retained in 

hydrocarbon liquids after flashing in tankage at STP 

conditions. Annual samples must be taken according to 

methods set forth in §98.234(b) to determine retention of 

CO2 in hydrocarbon liquids immediately downstream of the 

storage tank. Use the annual analysis for the calendar 

year.

(2) Estimate emissions using Equation W-38 of this 

section.

Masss,CO2 = Shl * Vhl (Eq. W-38)

Where:

Masss,CO2 = Annual CO2 emissions from CO2 retained in 

hydrocarbon liquids produced through EOR 

operations beyond tankage, in metric tons.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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Shl = Amount of CO2 retained in hydrocarbon liquids 

in metric tons per barrel, under standard 

conditions.

Vhl = Total volume of hydrocarbon liquids produced 

at the EOR operations in barrels in the 

calendar year.

(y) [Reserved] 

(z) Onshore petroleum and natural gas production and 

natural gas distribution combustion emissions. Calculate 

CO2 CH4, and N2O combustion-related emissions from 

stationary or portable equipment, except as specified in 

paragraph (z)(3) of this section, as follows:

(1) If the fuel combusted in the stationary or 

portable equipment is listed in Table C-1 of subpart C of 

this part, or is a blend of fuels listed in Table C-1, use 

the Tier 1 methodology described in subpart C of this part 

(General Stationary Fuel Combustion Sources). If the fuel 

combusted is natural gas and is pipeline quality and has a 

minimum high heat value of 950 Btu per standard cubic foot, 

then the natural gas emission factor and high heat values 

listed in Tables C-1 and C-2 of this part may be used.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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(2) For fuel combustion units that combust field gas 

or process vent gas, or any blend of field gas or process 

vent gas and fuels listed in Table C-1 of subpart C of this 

part, calculate combustion emissions as follows: 

(i) If you have a continuous flow meter on the 

combustion unit, you must use the measured flow volumes to 

calculate the total flow of gas to the unit. If you do not 

have a permanent flow meter on the combustion unit, you may 

install a permanent flow meter on the combustion unit, or 

use company records or engineering calculations based on 

best available data on heat duty or horsepower to estimate 

volumetric unit gas flow. 

(ii) If you have a continuous gas composition 

analyzer on fuel to the combustion unit, you must use these 

compositions for determining the concentration of gas 

hydrocarbon constituent in the flow of gas to the unit. If 

you do not have a continuous gas composition analyzer on 

gas to the combustion unit, you must use the appropriate 

gas compositions for each stream of hydrocarbons going to 

the combustion unit as specified in paragraph (u)(2)(i) of 

this section.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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(iii) Calculate GHG volumetric emissions at actual 

conditions using Equations W-39 of this section.

  

j

Ea CO Va YCO* Va *Yj* Rj( * ) , 2 2 

  

j

Ea CO Va YCO Va Yj Rj( * ) * * * , 2 2  (Eq. W-39A)

  Ea,CH 4  Va * 1 *YCH 4 (Eq. W-39B)

Where:

Ea,CO2 = Contribution of annual emissions from portable 

or stationary fuel combustion sources in cubic 

feet, under actual conditions.

Ea,CH4 = Contribution of annual CH4 emissions from 

portable or stationary fuel combustion sources 

in cubic feet, under actual conditions.

η = Combustion efficiency for portable and 

stationary equipment determined based on 

engineering estimation. 

Va = Volume of gas sent to combustion unit in cubic 

feet, during the year.

Yj = Concentration of gas hydrocarbon constituents 

j (such as methane, ethane, propane, butane, 

and pentanes plus) in gas sent to combustion 

unit.

YCH4 = Concentration of methane constituent in gas 

sent to combustion unit.

YCO2 = Concentration of CO2 constituent in gas sent 

to combustion unit.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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Rj = Number of carbon atoms in the gas hydrocarbon 

constituent j; 1 for methane, 2 for ethane, 3 

for propane, 4 for butane, and 5 for pentanes 

plus) in gas sent to combustion unit.

(iv) Calculate GHG volumetric emissions at standard 

conditions using calculations in paragraph (t) of this 

section.

(v) Calculate both combustion-related CH4 and CO2 mass 

emissions from volumetric CH4 and CO2 emissions using 

calculation in paragraph (v) of this section.

(vi) Calculate N2O mass emissions using Equation W-40 

of this section.

N O     Fuel  HHV  EF 

3

2 1 10 (Eq. W-40)

Where:

N2O = Annual N2O emissions from the combustion of a 

particular type of fuel (metric tons).

Fuel = Mass or volume of the fuel combusted (mass 

or volume per year, choose appropriately to 

be consistent with the units of HHV).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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HHV = For the high heat value for field gas or 

process vent gas, use 1.235 x 10-3 mmBtu/scf 

for HHV

EF = Use 1.0 × 10-4 kg N2O/mmBtu.

1 × 10-3 = Conversion factor from kilograms to metric 

tons.

(3) External fuel combustion sources with a rated 

heat capacity equal to or less than 5 mmBtu/hr do not need 

to report combustion emissions or include these emissions 

for threshold determination in §98.231(a). You must report 

the type and number of each external fuel combustion unit.

§98.234 Monitoring and QA/QC requirements.

The GHG emissions data for petroleum and natural gas 

emissions sources must be quality assured as applicable as 

specified in this section. Offshore petroleum and natural 

gas production facilities shall adhere to the monitoring 

and QA/QC requirements as set forth in 30 CFR 250.

(a) You must use any of the methods described as 

follows in this paragraph to conduct leak detection(s) of 

equipment leaks and through-valve leakage from all source 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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types listed in §98.233(k), (o), (p) and (q) that occur 

during a calendar year, except as provided in paragraph 

(a)(4) of this section. 

(1) Optical gas imaging instrument. Use an optical 

gas imaging instrument for equipment leak detection in 

accordance with 40 CFR part 60, subpart A, §60.18(i)(1) and 

(2) of the Alternative work practice for monitoring 

equipment leaks. Any emissions detected by the optical gas 

imaging instrument is a leak unless screened with Method 21 

(40 CFR part 60, appendix A-7) monitoring, in which case 

10,000 ppm or greater is designated a leak. In addition, 

you must operate the optical gas imaging instrument to 

image the source types required by this subpart in 

accordance with the instrument manufacturer’s operating 

parameters.

(2) Method 21. Use the equipment leak detection 

methods in 40 CFR part 60, appendix A-7, Method 21. If 

using Method 21 monitoring, if an instrument reading of 

10,000 ppm or greater is measured, a leak is detected. 

Inaccessible emissions sources, as defined in 40 CFR part 

60, are not exempt from this subpart. Owners or operators 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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must use alternative leak detection devices as described in 

paragraph(a)(1) of this section to monitor inaccessible 

equipment leaks or vented emissions. 

(3) Infrared laser beam illuminated instrument. Use 

an infrared laser beam illuminated instrument for equipment 

leak detection. Any emissions detected by the infrared 

laser beam illuminated instrument is a leak unless screened 

with Method 21 monitoring, in which case 10,000 ppm or 

greater is designated a leak. In addition, you must 

operate the infrared laser beam illuminated instrument to 

detect the source types required by this subpart in 

accordance with the instrument manufacturer’s operating 

parameters.

(4) Optical gas imaging instrument. An optical gas 

imaging instrument must be used for all source types that 

are inaccessible and cannot be monitored without elevating 

the monitoring personnel more than 2 meters above a support 

surface. 

(5) Acoustic leak detection device. Use the acoustic 

leak detection device to detect through-valve leakage. 

When using the acoustic leak detection device to quantify 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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the through-valve leakage, you must use the instrument 

manufacturer’s calculation methods to quantify the throughvalve leak. When using the acoustic leak detection device, 

if a leak of 3.1 scf per hour or greater is calculated, a 

leak is detected. In addition, you must operate the 

acoustic leak detection device to monitor the source valves 

required by this subpart in accordance with the instrument 

manufacturer’s operating parameters. 

(b) You must operate and calibrate all flow meters, 

composition analyzers and pressure gauges used to measure 

quantities reported in §98.233 according to the procedures 

in §98.3(i) and the procedures in paragraph (b) of this 

section. You may use an appropriate standard method 

published by a consensus-based standards organization if 

such a method exists or you may use an industry standard 

practice. Consensus-based standards organizations include, 

but are not limited to, the following: ASTM International, 

the American National Standards Institute (ANSI), the 

American Gas Association (AGA), the American Society of 

Mechanical Engineers (ASME), the American Petroleum 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Institute (API), and the North American Energy Standards 

Board (NAESB).

(c) Use calibrated bags (also known as vent bags) 

only where the emissions are at near-atmospheric pressures 

such that it is safe to handle and can capture all the 

emissions, below the maximum temperature specified by the 

vent bag manufacturer, and the entire emissions volume can 

be encompassed for measurement. 

(1) Hold the bag in place enclosing the emissions 

source to capture the entire emissions and record the time 

required for completely filling the bag. If the bag 

inflates in less than one second, assume one second 

inflation time.

(2) Perform three measurements of the time required 

to fill the bag, report the emissions as the average of the 

three readings.

(3) Estimate natural gas volumetric emissions at 

standard conditions using calculations in §98.233(t).

(4) Estimate CH4 and CO2 volumetric and mass emissions 

from volumetric natural gas emissions using the 

calculations in §98.233(u) and (v).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(d) Use a high volume sampler to measure emissions 

within the capacity of the instrument. 

(1) A technician following manufacturer instructions 

shall conduct measurements, including equipment 

manufacturer operating procedures and measurement 

methodologies relevant to using a high volume sampler, 

including positioning the instrument for complete capture 

of the equipment leak without creating backpressure on the 

source.

(2) If the high volume sampler, along with all 

attachments available from the manufacturer, is not able to 

capture all the emissions from the source then use antistatic wraps or other aids to capture all emissions without 

violating operating requirements as provided in the 

instrument manufacturer’s manual. 

(3) Estimate CH4 and CO2 volumetric and mass emissions 

from volumetric natural gas emissions using the 

calculations in §98.233(u) and (v).

(4) Calibrate the instrument at 2.5 percent methane 

with 97.5 percent air and 100 percent CH4 by using 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 290 of 520

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calibrated gas samples and by following manufacturer’s 

instructions for calibration.

(e) Peng Robinson Equation of State means the 

equation of state defined by Equation W-41 of this section:

2 2 V 2bV b

a

V b

RT

p

m m  m 









(Eq. W-41)

Where:

p = Absolute pressure.

R = Universal gas constant.

T = Absolute temperature.

Vm = Molar volume.

a = c

c

p

R T

2 2

0.45724

b = c

c

p

0.7780RT

α =  

2

2

1 0.37464 1.54226 0.26992 1

































   

Tc

T

 

Where:

ω = Acentric factor of the species.

Tc = Critical temperature.

Pc = Critical pressure.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(f) Special reporting provisions

(1) Best available monitoring methods. EPA will 

allow owners or operators to use best available monitoring 

methods for parameters in §98.233 Calculating GHG Emissions 

as specified in paragraphs (f)(2), (f)(3), and (f)(4) of 

this section. If the reporter anticipates the potential

need for best available monitoring for sources for which 

they need to petition EPA and the situation is unresolved 

at the time of the deadline, reporters should submit 

written notice of this potential situation to EPA by the 

specified deadline for requests to be considered. EPA 

reserves the right to review petitions after the deadline 

but will only consider and approve late petitions which 

demonstrate extreme or unusual circumstances. The 

Administrator reserves to right to request further 

information in regard to all petition requests. The owner 

or operator must use the calculation methodologies and 

equations in §98.233 Calculating GHG Emissions. Best 

available monitoring methods means any of the following 

methods specified in paragraph (f)(1) of this section: 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(i) Monitoring methods currently used by the facility 

that do not meet the specifications of this subpart. 

(ii) Supplier data.

(iii) Engineering calculations. 

(iv) Other company records. 

(2) Best available monitoring methods for wellrelated emissions. During January 1, 2011 through June 30, 

2011, owners or operators may use best available monitoring 

methods for any well-related data that cannot reasonably be 

measured according to the monitoring and QA/QC requirements 

of this subpart, and only where required measurements 

cannot be duplicated due to technical limitations after 

June 30, 2011. These well-related sources are:

(i) Gas well venting during well completions and 

workovers with hydraulic fracturing as specified in 

§98.233(g).

(ii) Well testing venting and flaring as specified in 

§98.233(l).

(3) Best available monitoring methods for specified 

activity data. During January 1, 2011 through June 30, 

2011, owners or operators may use best available monitoring 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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methods for activity data as listed below that cannot 

reasonably be obtained according to the monitoring and 

QA/QC requirements of this subpart, specifically for events 

that generate data that can be collected only between 

January 1, 2011 and June 30, 2011 and cannot be duplicated 

after June 30, 2011. These sources are:

(i) Cumulative hours of venting, days, or times of 

operation in §98.233(e), (f), (g), (h), (l), (o), (p), (q), 

and (r).

(ii) Number of blowdowns, completions, workovers, or 

other events in §98.233(f), (g), (h), (i), and (w).

(iii) Cumulative volume produced, volume input or 

output, or volume of fuel used in paragraphs §98.233(d), 

(e), (j), (k), (l), (m), (n), (x), (y), and (z).

(4) Best available monitoring methods for leak 

detection and measurement. The owner or operator may 

request use of best available monitoring methods between 

January 1, 2011 and December 31, 2011 for sources requiring 

leak detection and/or measurement. These sources include:

(i) Reciprocating compressor rod packing venting in 

onshore natural gas processing, onshore natural gas 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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transmission compression, underground natural gas storage, 

LNG storage, and LNG import and export equipment as 

specified in §98.232 (d)(1), (e)(1), (f)(1), (g)(1), and 

(h)(1).

(ii) Centrifugal compressor wet seal oil degassing 

venting in onshore natural gas processing, onshore natural 

gas transmission compression, underground natural gas 

storage, LNG storage, and LNG import and export equipment 

as specified in §98.232(d)(2), (e)(2), (f)(2), (g)(2), and 

(h)(2).

(iii) Acid gas removal vent stacks in onshore 

petroleum and natural gas production and onshore natural 

gas processing as specified in §98.232(c)(17) and (d)(6).

(iv) Equipment leak emissions from valves, 

connectors, open ended lines, pressure relief valves, block 

valves, control valves, compressor blowdown valves, orifice 

meters, other meters, regulators, vapor recovery 

compressors, centrifugal compressor dry seals, and/or other 

equipment leaks in onshore natural gas processing, onshore 

natural gas transmission compression, underground natural 

gas storage, LNG storage, LNG import and export equipment, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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and natural gas distribution as specified in §98.232 

(d)(7), (e)(7), (f)(5), (g)(3), (h)(4), and (i)(1).

(v) Condensate (oil and/or water) storage tanks in 

onshore natural gas transmission compression as specified 

in §98.232(e)(3).

(5) Requests for the use of best available monitoring 

methods. The owner or operator may submit a request to the 

Administrator to use one or more best available monitoring 

methods.

(i) No request or approval by the Administrator is 

necessary to use best available monitoring methods between 

January 1, 2011 and June 30, 2011 for the sources specified 

in paragraph (f)(2) of this section.

(ii) No request or approval by the Administrator is 

necessary to use best available monitoring methods between 

January 1, 2011 and June 30, 2011 for the sources specified 

in paragraph (f)(3) of this section.

(iii) Owners or operators must submit a request and 

receive approval by the Administrator to use best available 

monitoring methods between January 1, 2011 and December 31, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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2011 for sources specified in paragraph (f)(4) of this 

section.

(A) Timing of request. The request to use best 

available monitoring methods for paragraph (f)(4) of this 

section must be submitted to EPA no later than April 30, 

2011. 

(B) Content of request. Requests must contain the 

following information for sources listed in paragraph 

(f)(4) of this section:

(1) A list of specific source types and specific 

equipment, monitoring instrumentation, and/or services for 

which the request is being made and the locations where 

each piece of monitoring instrumentation will be installed 

or monitoring service will be supplied.

(2) Identification of the specific rule requirements 

(by subpart, section, and paragraph number) for which the 

instrumentation or monitoring service is needed.

(3) Documentation which demonstrates that the owner 

or operator made all reasonable efforts to obtain the 

information, services or equipment necessary to comply with 

subpart W reporting requirements, including evidence of 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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specific service or equipment providers contacted and why 

services or information could not be obtained during 2011.

(4) A description of the specific actions the 

facility will take to obtain and/or install the equipment 

or obtain the monitoring service as soon as reasonably 

feasible and the expected date by which the equipment will 

be obtained and operating or service will be provided.

(C) Approval criteria. To obtain approval, the owner 

or operator must demonstrate to the Administrator’s 

satisfaction that it does not own the required monitoring 

equipment, and it is not reasonably feasible to acquire, 

install, and operate a required piece of monitoring 

equipment or to obtain leak detection or measurement 

services in order to meet the requirements of this subpart 

for 2011.

(iv) EPA does not anticipate a need to approve the use 

of best available monitoring methods for sources not listed 

in paragraphs(f)(2), (f)(3), and (f)(4) of this section; 

however, EPA will review such requests if submitted in 

accordance with paragraph (f)(5)(iv)(A)-(C) of this 

section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(A) Timing of request. The request to use best 

available monitoring methods for sources not listed in 

paragraphs (f)(2), (f)(3), and (f)(4) of this section must 

be submitted to EPA no later than April 30, 2011. 

(B) Content of request. Requests must contain the 

following information:

(1) A list of specific source categories and 

parameters for which the owner or operator is seeking use 

of best available monitoring methods.

(2) A description of the data collection 

methodologies that do not meet safety regulations, 

technical infeasibility, or specific laws or regulations 

that conflict with each specific source for which an owner 

or operator is requesting use of best available monitoring 

methodologies. 

(3) A detailed explanation and supporting 

documentation of how and when the owner or operator will 

receive the services or equipment to comply with all 

subpart W reporting requirements. 

(C) Approval criteria. To obtain approval, the owner 

or operator must demonstrate to the Administrator’s 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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satisfaction that the owner or operator faces unique 

safety, technical or legal issues rendering them unable to 

meet the requirements of this subpart for 2011.

(6) Requests for extension of the use of best 

available monitoring methods through December 31, 2011 for 

sources in paragraph (f)(2) of this section. The owner or 

operator may submit a request to the Administrator to use 

one or more best available monitoring methods described in 

paragraph (f)(2) of this section beyond June 30, 2011. 

(i) Timing of request. The extension request must be 

submitted to EPA no later than April 30, 2011. 

(ii) Content of request. Requests must contain the 

following information:

(A) A list of specific source types and specific 

equipment, monitoring instrumentation, contract 

modifications, and/or services for which the request is 

being made and the locations where each piece of monitoring 

instrumentation will be installed, monitoring service will 

be supplied, or contracts will be modified. 

(B) Identification of the specific rule requirements 

(by subpart, section, and paragraph number) for which the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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instrumentation, contract modification, or monitoring 

service is needed. 

(C) A description and applicable correspondence 

outlining the diligent efforts of the owner or operator in 

obtaining the needed equipment or service and why they 

could not be obtained and installed in a period of time 

enabling completion of applicable requirements of this 

subpart within the 2011 calendar year. 

(D) If the reason for the extension is that the owner 

or operator cannot collect data from a service provider or 

relevant organization in order for the owner or operator to 

meet requirements of this subpart for the 2011 calendar 

year, the owner or operator must demonstrate a good faith 

effort that it is not possible to obtain the necessary 

information, service or hardware which may include 

providing correspondence from specific service providers or 

other relevant entities to the owner or operator, whereby 

the service provider states that it is unable to provide 

the necessary data or services requested by the owner or 

operator that would enable the owner or operator to comply 

with subpart W reporting requirements by June 30, 2011. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(E) A description of the specific actions the owner 

or operator will take to comply with monitoring 

requirements in 2012 and beyond.

(iii) Approval criteria. To obtain approval, the 

owner or operator must demonstrate to the Administrator’s 

satisfaction that it is not reasonably feasible to obtain 

the data necessary to meet the requirements of this subpart 

for the sources specified in paragraph (f)(2) of this 

section by June 30, 2011. 

(7) Requests for extension of the use of best 

available monitoring methods through December 31, 2011 for 

sources in paragraph (f)(3) of this section. The owner or 

operator may submit a request to the Administrator to use 

one or more best available monitoring methods described in 

paragraph (f)(3) of this section beyond June 30, 2011. 

(i) Timing of request. The extension request must be 

submitted to EPA no later than April 30, 2011. 

(ii) Content of request. Requests must contain the 

following information:

(A) A list of specific source types for which data 

collection could not be implemented.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(B) Identification of the specific rule requirements 

(by subpart, section, and paragraph number) for which the 

data collection could not be implemented. 

(C) A description of the data collection 

methodologies that do not meet safety regulations, 

technical infeasibility, or specific laws or regulations 

that conflict with each specific source for which an owner 

or operator is requesting use of best available monitoring 

methodologies for which data collection could not be 

implemented in the 2011 calendar year.

(iii) Approval criteria. To obtain approval, the 

owner or operator must demonstrate to the Administrator’s 

satisfaction that it is not reasonably feasible to 

implement the data collection for the sources described in 

paragraph (f)(3) of this section for the methods required 

in this subpart by June, 30, 2011.

(8) Requests for extension of the use of best 

available monitoring methods beyond 2011 for sources listed 

in paragraphs (f)(2), (f)(3), (f)(4), (f)(5)(iv) of this 

section and other sources in this subpart. EPA does not 

anticipate a need for approving the use of best available 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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methods beyond December 31, 2011, except in extreme 

circumstances, which include safety, a requirement being 

technically infeasible or counter to other local, State, or 

Federal regulations. 

(i) Timing of request. The request to use best 

available monitoring methods for paragraphs (f)(2), (f)(3), 

(f)(4), (f)(5)(iv) of this section and sources not listed 

in paragraphs (f)(2), (f)(3), (f)(4), (f)(5)(iv) of this 

section must be submitted to EPA no later than September 

30, 2011. 

(ii) Content of request. Requests must contain the 

following information: 

(iii) A list of specific source categories and 

parameters for which the owner or operator is seeking use 

of best available monitoring methods.

(iv) A description of the data collection 

methodologies that do not meet safety regulations, 

technical infeasibility, or specific laws or regulations 

that conflict with each specific source for which an owner 

or operator is requesting use of best available monitoring 

methodologies. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(v) A detailed explanation and supporting 

documentation of how and when the owner or operator will 

receive the services or equipment to comply with all of 

this subpart W reporting requirements. 

(C) Approval criteria. To obtain approval, the owner 

or operator must demonstrate to the Administrator’s 

satisfaction that the owner or operator faces unique 

safety, technical or legal issues rendering them unable to 

meet the requirements of this subpart.

§98.235 Procedures for estimating missing data.

A complete record of all estimated and/or measured 

parameters used in the GHG emissions calculations is 

required. If data are lost or an error occurs during 

annual emissions estimation or measurements, you must 

repeat the estimation or measurement activity for those 

sources as soon as possible, including in the subsequent 

calendar year if missing data are not discovered until 

after December 31 of the year in which data are collected, 

until valid data for reporting is obtained. Data developed 

and/or collected in a subsequent calendar year to 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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substitute for missing data cannot be used for that 

subsequent year’s emissions estimation. Where missing data 

procedures are used for the previous year, at least 30 days 

must separate emissions estimation or measurements for the 

previous year and emissions estimation or measurements for 

the current year of data collection. For missing data which 

are continuously monitored or measured, (for example flow 

meters), or for missing temperature or pressure data that 

are required under §98.236, the reporter may use best 

available data for use in emissions determinations. The 

reporter must record and report the basis for the best 

available data in these cases.

§98.236 Data reporting requirements.

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

each annual report must contain reported emissions and 

related information as specified in this section.

(a) Report annual emissions separately for each of 

the industry segments listed in paragraphs (a)(1) through 

(8) of this section in metric tons CO2e per year at standard 

conditions. For each segment, report emissions from each 

source type §98.232(a) in the aggregate, unless specified 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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otherwise. For example, an onshore natural gas production 

operation with multiple reciprocating compressors must 

report emissions from all reciprocating compressors as an 

aggregate number.

(1) Onshore petroleum and natural gas production.

(2) Offshore petroleum and natural gas production.

(3) Onshore natural gas processing.

(4) Onshore natural gas transmission compression.

(5) Underground natural gas storage.

(6) LNG storage.

(7) LNG import and export.

(8) Natural gas distribution. Report each source in 

the aggregate for pipelines and for Metering and Regulating 

(M&R) stations.

(b) Offshore petroleum and natural gas production is 

not required to report activity data and emissions for each 

aggregated source under §98.236 (c). Reporting requirements 

for offshore petroleum and natural gas production is set 

forth by BOEMRE in compliance with 30 CFR 250.302 through 

304.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(c) For each aggregated source, unless otherwise 

specified, report activity data and emissions (in metric 

tons CO2e per year at standard conditions) for each 

aggregated source type as follows:

(1) For natural gas pneumatic devices (refer to 

Equation W-1 of §98.233), report the following: 

(i) Actual count and estimated count separately of 

natural gas pneumatic high bleed devices as applicable.

(ii) Actual count and estimated count separately of 

natural gas pneumatic low bleed devices as applicable. 

(iii) Actual count and estimated count separately of 

natural gas pneumatic intermittent bleed devices as 

applicable. 

(iv) Report emissions collectively. 

(2) For natural gas driven pneumatic pumps (refer to 

Equation W-2 of §98.233), report the following, 

(i) Count of natural gas driven pneumatic pumps.

(ii) Report emissions collectively. 

(3) For each acid gas removal unit (refer to Equation 

W-3 and Equation W-4 of §98.233), report the following:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(i) Total throughput off the acid gas removal unit 

using a meter or engineering estimate based on process 

knowledge or best available data in million cubic feet per 

year.

(ii) For Calculation Methodology 1 and Calculation 

Methodology 2 of §98.233(d), fraction of CO2 content in the 

vent from the acid gas removal unit (refer to 

§98.233(d)(6)).

(iii) For Calculation Methodology 3 of §98.233(d), 

volume fraction of CO2 content of natural gas into and out 

of the acid gas removal unit (refer to §98.233(d)(7) and 

(d)(8)).

(iv) Report emissions from the AGR unit recovered and 

transferred outside the facility.

(v) Report emissions individually. 

(4) For dehydrators, report the following:

(i) For each Glycol dehydrator with a throughput 

greater than or equal to 0.4 MMscfd (refer to 

§98.233(e)(1)), report the following: 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(A) Glycol dehydrator feed natural gas flow rate in 

MMscfd, determined by engineering estimate based on best 

available data.

(B) Glycol dehydrator absorbent circulation pump 

type.

(C) Whether stripper gas is used in glycol 

dehydrator. 

(D) Whether a flash tank separator is used in glycol 

dehydrator. 

(E) Type of absorbent.

(F) Total time the glycol dehydrator is operating in 

hours.

(G) Temperature, in degrees Fahrenheit and pressure, 

in psig, of the wet natural gas.

(H) Concentration of CH4 and CO2 in natural gas.

(I) What vent gas controls are used (refer to 

§98.233(e)(3) and (e)(4)). 

(J) Report vent and flared emissions individually. 

(ii) For all glycol dehydrators with a throughput 

less than 0.4 MMscfd (refer to §98.233, Equation W-5 of 

§98.233), report the following:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(A) Count of glycol dehydrators.

(B) Whether any vent gas controls are used (refer to 

§98.233(e)(3) and (e)(4)).

(C) Report vent emissions collectively. 

(iii) For absorbent desiccant dehydrators (refer to 

Equation W-6 of §98.233), report the following:

(A) Count of desiccant dehydrators.

(B) Report emissions collectively. 

(5) For well venting for liquids unloading (refer to 

Equations W-7, W-8 and W-9 of §98.233), report the 

following by field:

(i) Count of wells vented to the atmosphere for 

liquids unloading.

(ii) Count of plunger lifts.

(iii) Cumulative number of unloadings vented to the 

atmosphere.

(iv) Average flow rate of the measured well venting 

in cubic feet per hour (refer to §98.233(f)(1)(i)(A)).

(v) Average casing diameter in inches.

(vi) Report emissions collectively. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(6) For well completions and workovers, report the 

following for each field: 

(i) For gas well completions and workovers with 

hydraulic fracturing (refer to Equation W-10 of §98.233):

(A) Total count of completions in calendar year.

(B) Average flow rate of the measured well completion 

venting in cubic feet per hour (refer to §98.233(g)(1)(i)

or (g)(1)(ii)).

(C) Total count of workovers in calendar year.

(D) Average flow rate of the measured well workover 

venting in cubic feet per hour (refer to §98.233(g)(1)(i) 

or (g)(1)(ii)).

(E) Total number of days of gas venting to the 

atmosphere during backflow for completion. 

(F) Total number of days of gas venting to the 

atmosphere during backflow for workovers.

(G) Report number of completions and workovers 

employing reduced emissions completions and engineering 

estimate based on best available data of the amount of gas 

recovered to sales.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(H) Report vent emissions collectively. Report 

flared emissions collectively.

Report vent emissions collectively. Report flared 

emissions collectively. 

(ii) For gas well completions and workovers without 

hydraulic fracturing (refer to Equation W-13 of §98.233): 

(A) Total count of completions in calendar year.

(B) Total count of workovers in calendar year that 

flare gas or vent gas to the atmosphere.

(C) Total number of days of gas venting to the 

atmosphere during backflow for completion. 

(D) Report vent emissions collectively. Report flared 

emissions collectively.

(7) For each blowdown vent stack (refer to Equation 

W-14 of §98.233), report the following:

(i) Total number of blowdowns per unique volume type 

in calendar year. 

(ii) Report emissions collectively per equipment 

type. 

(8) For gas emitted from produced oil sent to 

atmospheric tanks: 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(i) For wellhead gas-liquid separator with oil 

throughput greater than or equal to 10 barrels per day, 

using Calculation Methodology 1 and 2 of §98.233(j), report 

the following by field: 

(A) Number of wellhead separators sending oil to 

atmospheric tanks.

(B) Estimated average separator temperature, in 

degrees Fahrenheit, and estimated average pressure, in 

psig.

(C) Estimated average sales oil stabilized API 

gravity, in degrees.

(D) Count of hydrocarbon tanks at well pads.

(E) Best estimate of count of stock tanks not at well 

pads receiving your oil.

(F) Total volume of oil from all wellhead separators 

sent to tank(s) in barrels per year.

(G) Count of tanks with emissions control measures, 

either vapor recovery system or flaring, for tanks at well 

pads.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(H) Best estimate of count of stock tanks assumed to 

have emissions control measures not at well pads, receiving 

your oil.

(I) Range of concentrations of flash gas, CH4 and CO2.

(J) Report emissions individually for Calculation 

Methodology 1 and 2 of §98.233(j). 

(ii) For wells with oil production greater than or 

equal to 10 barrels per day, using Calculation Methodology 

3 and 4 of §98.233(j), report the following by field: 

(A) Total volume of sales oil from all wells in 

barrels per year.

(B) Total number of wells sending oil directly to 

tanks.

(C) Total number of wells sending oil to separators 

off the well pads.

(D) Sales oil API gravity range for (B) and (C) of 

this section, in degrees. 

(E) Count of hydrocarbon tanks on wellpads

(F) Count of hydrocarbon tanks, both on and off well 

pads assumed to have emissions control measures: either 

vapor recovery system or flaring of tank vapors.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(G) Report emissions collectively for Calculation 

Methodology 3 and 4 of §98.233(j). 

(iii) For wellhead gas-liquid separators and wells 

with throughput less than 10 barrels per day, using 

Calculation Methodology 5 of §98.233(j) Equation W-15 of 

§98.233), report the following:

(A) Number of wellhead separators.

(B) Number of wells without wellhead separators.

(C) Total volume of oil production in barrels per 

year. 

(D) Best estimate of fraction of production sent to 

tanks with assumed control measures: either vapor recovery 

system or flaring of tank vapors.

(E) Count of hydrocarbon tanks on well pads.

(F) Report CO2 and CH4 emissions collectively. 

(iv) If wellhead separator dump valve is functioning 

improperly during the calendar year (refer to Equation W-16 

of §98.233), report the following:

(A) Count of wellhead separators that dump valve 

factor is applied. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(9) For transmission tank emissions identified using 

optical gas imaging instrument per §98.234(a) (refer to 

§98.233(k)), or acoustic leak detection of scrubber dump 

valves report the following for each tank:

(i) Report emissions individually.

(ii) [Reserved]

(10) For well testing (refer to Equation W-17 of 

§98.233), report the following for each basin:

(i) Number of wells tested per basin in calendar 

year.

(ii) Average gas to oil ratio for each basin.

(iii) Average number of days the well is tested in a 

basin.

(iv) Report emissions of the venting gas 

collectively.

(11) For associated natural gas venting (refer to 

Equation W-18 of §98.233), report the following for each 

basin:

(i) Number of wells venting or flaring associated 

natural gas in a calendar year.

(ii) Average gas to oil ratio for each basin.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(iii) Report emissions of the flaring gas 

collectively. 

(12) For flare stacks (refer to Equation W-19, W-20, 

and W-21 of §98.233), report the following for each flare:

(i) Whether flare has a continuous flow monitor.

(ii) Volume of gas sent to flare in cubic feet per 

year.

(iii) Percent of gas sent to un-lit flare determined 

by engineering estimate and process knowledge based on best 

available data and operating records.

(iv) Whether flare has a continuous gas analyzer.

(v) Flare combustion efficiency. 

(vi) Report uncombusted and combusted CO2 and CH4 

emissions separately. 

(13) For each centrifugal compressor:

(i) For compressors with wet seals in operational 

mode (refer to Equations W-22 through W-24 of §98.233), 

report the following for each degassing vent:

(A) Number of wet seals connected to the degassing 

vent.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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(B) Fraction of vent gas recovered for fuel or sales 

or flared.

(C) Annual throughput in million scf, use an 

engineering calculation based on best available data.

(D) Type of meters used for making measurements.

(E) Reporter emission factor for wet seal oil 

degassing vents in cubic feet per hour (refer to Equation 

W-24 of §98.233).

(F) Total time the compressor is operating in hours. 

(G) Report seal oil degassing vent emissions for 

compressors measured (refer to Equation W-22 of §98.233) 

and for compressors not measured (refer to Equation W-23

and Equation W-24 of §98.233).

(ii) For wet and dry seal centrifugal compressors in 

operating mode, (refer to Equations W-22 through W-24 of 

§98.233), report the following:

(A) Total time in hours the compressor is in 

operating mode.

(B) Reporter emission factor for blowdown vents in 

cubic feet per hour (refer to Equation W-24 of §98.233).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(C) Report blowdown vent emissions when in operating 

mode (refer to Equation W-23 and Equation W-24 of §98.233). 

(iii) For wet and dry seal centrifugal compressors in 

not operating, depressurized mode (refer to Equations W-22 

through W-24 of §98.233), report the following:

(A) Total time in hours the compressor is in 

shutdown, depressurized mode.

(B) Reporter emission factor for isolation valve 

emissions in shutdown, depressurized mode in cubic feet per 

hour (refer to Equation W-24 of §98.233).

(C) Report the isolation valve leakage emissions in 

not operating, depressurized mode in cubic feet per hour 

(refer to Equation W-23 and Equation W-24 of §98.233). 

(iv) Report total annual compressor emissions from 

all modes of operation (refer to Equation W-24 of §98.233).

(v) For centrifugal compressors in onshore petroleum 

and natural gas production (refer to Equation W-25 of 

§98.233), report the following:

(A) Count of compressors.

(B) Report emissions (refer to Equation W-25 of 

§98.233) collectively. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(14) For reciprocating compressors:

(i) For reciprocating compressors rod packing 

emissions with or without a vent in operating mode, report 

the following:

(A) Annual throughput in million scf, use an 

engineering calculation based on best available data. 

(B) Total time in hours the reciprocating compressor 

is in operating mode.

(C) Report rod packing emissions for compressors 

measured (refer to Equation W-26 of §98.233) and for 

compressors not measured (refer to Equation W-27 and 

Equation W-28 of §98.233).

(ii) For reciprocating compressors blowdown vents not 

manifold to rod packing vents, in operating and standby 

pressurized mode (refer to Equations W-26 through W-28 of 

§98.233), report the following: 

(A) Total time in hours the compressor is in standby, 

pressurized mode. 

(B) Reporter emission factor for blowdown vents in 

cubic feet per hour (refer to §98.233, Equation W-28).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(C) Report blowdown vent emissions when in operating 

and standby pressurized modes (refer to Equation W-27 and 

Equation W-28 of §98.233). 

(iii) For reciprocating compressors in not operating, 

depressurized mode (refer to Equations W-26 through W-28 of 

§98.233), report the following:

(A) Total time the compressor is in not operating, 

depressurized mode.

(B) Reporter emission factor for isolation valve 

emissions in not operating, depressurized mode in cubic 

feet per hour (refer to Equation W-28 of §98.233).

(C) Report the isolation valve leakage emissions in 

not operating, depressurized mode. 

(iv) Report total annual compressor emissions from all 

modes of operation (refer to Equation W-27 and Equation W28 of §98.233).

(v) For reciprocating compressors in onshore 

petroleum and natural gas production (refer to Equation W29 of §98.233), report the following:

(A) Count of compressors.

(B) Report emissions collectively. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Page 322 of 520

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(15) For each equipment leak sources that uses 

emission factors for estimating emissions (refer to 

§98.233(q) and (r).

(i) For equipment leaks found in each leak survey 

(refer to §98.233(q)), report the following:

(A) Total count of leaks found in each complete 

survey listed by date of survey and each type of leak 

source for which there is a leaker emission factor in 

Tables W-2, W-3, W-4, W-5, W-6, and W-7 of this subpart.

(B) Concentration of CH4 and CO2 as described in 

Equation W-30 of §98.233.

(C) Report CH4 and CO2 emissions (refer to Equation W30 of §98.233) collectively by equipment type.

(ii) For equipment leaks calculated using population 

counts and factors (refer to §98.233(r)), report the 

following:

(A) For source categories §98.230(a)(3), (a)(4), 

(a)(5), (a)(6), and (a)(7), total count for each type of 

leak source in Tables W-2, W-3, W-4, W-5, and W-6 of this 

subpart for which there is a population emission factor, 

listed by major heading and component type.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(B) For onshore production (refer to §98.230

paragraph (a)(2)), total count for each type of major 

equipment in Table W-1B and Table W-1C of this subpart, by 

field.

(C) Report CH4 and CO2 emissions (refer to Equation W31 of §98.233) collectively by equipment type.

(16) For local distribution companies, report the 

following:

(i) Number of custody transfer gate stations.

(ii) Number of non-custody transfer gate stations.

(iii) Custody transfer gate station meter run leak 

factor (refer to Equation W-32 of §98.233).

(iv) Number of below grade M&R stations with inlet 

pressure greater than 300 psig.

(v) Number of below grade M&R stations with inlet 

pressure between 100 and 300 psig.

(vi) Number of below grate M&R stations with inlet 

pressure less than 100 psig. 

(vii) Number of miles of unprotected steel 

distribution mains.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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(viii) Number of miles of protected steel distribution 

mains.

(ix) Number of miles of plastic distribution mains.

(x) Number of miles of cast iron distribution mains.

(xi) Number of unprotected steel distribution 

services.

(xii) Number of protected steel distribution services.

(xiii) Number of plastic distribution services. 

(xiv) Number of copper distribution services.

(xv) Total emissions from each natural gas distribution facility. 

(17) For each EOR injection pump blowdown (refer to 

Equation W-37 of §98.233), report the following:

(i) Pump capacity, in barrels per day.

(ii) Volume of critical phase gas between isolation 

valves.

(iii) Number of blowdowns per year.

(iv) Critical phase EOR injection gas density.

(v) Report emissions collectively. 

(18) For EOR hydrocarbon liquids dissolved CO2 for 

each field (refer to Equation W-38 of §98.233), report the 

following:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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(i) Volume of crude oil produced in barrels per year.

(ii) Amount of CO2 retained in hydrocarbon liquids in 

metric tons per barrel, under standard conditions. 

(iii) Report emissions individually.

(19) For onshore petroleum and natural gas production 

and natural gas distribution combustion emissions, report 

the following:

(i) Cumulative number of external fuel combustion 

units with a rated heat capacity equal to or less than 5 

mmBtu/hr, by type of unit.

(ii) Cumulative number of external fuel combustion 

units with a rated heat capacity larger than 5 mmBtu/hr, by 

type of unit.

(iii) Cumulative emissions from external fuel 

combustion units with a rated heat capacity larger than 5 

mmBtu/hr, by type of unit.

(iv) Cumulative volume of fuel combusted in external 

fuel combustion units with a rated heat capacity larger 

than 5 mmBtu/hr, by fuel type.

(v) Cumulative number of all internal combustion 

units, by type of unit. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(vi) Cumulative emissions from internal combustion 

units, by type of unit. 

(vii) Cumulative volume of fuel combusted in internal 

combustion units, by fuel type.

(d) Report annual throughput as determined by 

engineering estimate based on best available data for each 

industry segment listed in paragraphs (a)(1) through (a)(8) 

of this section. 

§98.237 Records that must be retained.

Monitoring Plans, as described in §98.3(g)(5), must be 

completed by April 1, 2011. In addition to the information 

required by §98.3(g), you must retain the following 

records: 

(a) Dates on which measurements were conducted.

(b) Results of all emissions detected and 

measurements.

(c) Calibration reports for detection and measurement 

instruments used.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Page 327 of 520

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(d) Inputs and outputs of calculations or emissions 

computer model runs used for engineering estimation of 

emissions.

§98.238 Definitions.

Except as provided in this section, all terms used in 

this subpart have the same meaning given in the Clean Air 

Act and subpart A of this part.

Acid gas means hydrogen sulfide (H2S) and/or carbon 

dioxide (CO2) contaminants that are separated from sour 

natural gas by an acid gas removal unit.

Acid gas removal unit (AGR) means a process unit that 

separates hydrogen sulfide and/or carbon dioxide from sour 

natural gas using liquid or solid absorbents or membrane 

separators.

Acid gas removal vent emissions mean the acid gas 

separated from the acid gas absorbing medium (e.g., an 

amine solution) and released with methane and other light 

hydrocarbons to the atmosphere or a flare.

Basin means geologic provinces as defined by the 

American Association of Petroleum Geologists (AAPG) 

Geologic Note: AAPG-CSD Geologic Provinces Code Map: AAPG 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 328 of 520

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Bulletin, Prepared by Richard F. Meyer, Laure G. Wallace, 

and Fred J. Wagner, Jr., Volume 75, Number 10 (October 

1991) (incorporated by reference, see §98.7) and the Alaska 

Geological Province Boundary Map, Compiled by the American 

Association of Petroleum Geologists Committee on Statistics 

of Drilling in Cooperation with the USGS, 1978

(incorporated by reference, see §98.7).

Component means each metal to metal joint or seal of 

non-welded connection separated by a compression gasket, 

screwed thread (with or without thread sealing compound), 

metal to metal compression, or fluid barrier through which 

natural gas or liquid can escape to the atmosphere.

Compressor means any machine for raising the pressure 

of a natural gas or CO2 by drawing in low pressure natural 

gas or CO2 and discharging significantly higher pressure 

natural gas or CO2.

Condensate means hydrocarbon and other liquid, 

including both water and hydrocarbon liquids, separated 

from natural gas that condenses due to changes in the 

temperature, pressure, or both, and remains liquid at 

storage conditions. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Engineering estimation, for purposes of subpart W,

means an estimate of emissions based on engineering 

principles applied to measured and/or approximated physical 

parameters such as dimensions of containment, actual 

pressures, actual temperatures, and compositions.

Enhanced oil recovery (EOR) means the use of certain 

methods such as water flooding or gas injection into 

existing wells to increase the recovery of crude oil from a 

reservoir. In the context of this subpart, EOR applies to 

injection of critical phase or immiscible carbon dioxide 

into a crude oil reservoir to enhance the recovery of oil. 

Equipment leak means those emissions which could not 

reasonably pass through a stack, chimney, vent, or other 

functionally-equivalent opening.

Equipment leak detection means the process of 

identifying emissions from equipment, components, and other 

point sources.

External combustion means fired combustion in which 

the flame and products of combustion are separated from 

contact with the process fluid to which the energy is 

delivered. Process fluids may be air, hot water, or 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 330 of 520

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hydrocarbons. External combustion equipment may include 

fired heaters, industrial boilers, and commercial and 

domestic combustion units.

Facility with respect to natural gas distribution for 

purposes of this subpart and for subpart A means the 

collection of all distribution pipelines, metering 

stations, and regulating stations that are operated by a 

Local Distribution Company (LDC) that is regulated as a 

separate operating company by a public utility commission 

or that are operated as an independent municipally-owned 

distribution system.

Facility with respect to onshore petroleum and natural 

gas production for purposes of this subpart and for subpart 

A means all petroleum or natural gas equipment on a well 

pad or associated with a well pad and CO2 EOR operations 

that are under common ownership or common control including 

leased, rented, or contracted activities by an onshore 

petroleum and natural gas production owner or operator and 

that are located in a single hydrocarbon basin as defined 

in §98.238. Where a person or entity owns or operates more 

than one well in a basin, then all onshore petroleum and 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 331 of 520

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natural gas production equipment associated with all wells 

that the person or entity owns or operates in the basin 

would be considered one facility. 

Farm Taps are pressure regulation stations that 

deliver gas directly from transmission pipelines to 

generally rural customers. The gas may or may not be 

metered, but always does not pass through a city gate 

station. In some cases a nearby LDC may handle the billing 

of the gas to the customer(s). 

Field means oil and gas fields identified in the 

United States as defined by the Energy Information 

Administration Oil and Gas Field Code Master List 2008, 

DOE/EIA 0370(08) (incorporated by reference, see §98.7).

Flare stack emissions means CO2 and N2O from partial 

combustion of hydrocarbon gas sent to a flare plus CH4

emissions resulting from the incomplete combustion of 

hydrocarbon gas in flares.

Flare combustion efficiency means the fraction of 

hydrocarbon gas, on a volume or mole basis, that is 

combusted at the flare burner tip.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Gas well means a well completed for production of 

natural gas (including condensate) from one or more gas 

zones or reservoirs. Such wells contain no completions for 

the production of crude oil.

Internal combustion means the combustion of a fuel 

that occurs with an oxidizer (usually air) in a combustion 

chamber. In an internal combustion engine the expansion of 

the high-temperature and –pressure gases produced by 

combustion applies direct force to a component of the 

engine, such as pistons, turbine blades, or a nozzle. This 

force moves the component over a distance, generating 

useful mechanical energy. Internal combustion equipment may 

include gasoline and diesel industrial engines, natural 

gas-fired reciprocating engines, and gas turbines.

Liquefied natural gas (LNG) means natural gas 

(primarily methane) that has been liquefied by reducing its 

temperature to -260 degrees Fahrenheit at atmospheric 

pressure.

LNG boil-off gas means natural gas in the gaseous 

phase that vents from LNG storage tanks due to ambient heat 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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leakage through the tank insulation and heat energy 

dissipated in the LNG by internal pumps.

Offshore means seaward of the terrestrial borders of 

the United States, including waters subject to the ebb and 

flow of the tide, as well as adjacent bays, lakes or other 

normally standing waters, and extending to the outer 

boundaries of the jurisdiction and control of the United 

States under the Outer Continental Shelf Lands Act. 

Oil well means a well completed for the production of 

crude oil from at least one oil zone or reservoir.

Onshore petroleum and natural gas production owner or 

operator means the person or entity who holds the permit to 

operate petroleum and natural gas wells on the drilling 

permit or an operating permit where no drilling permit is 

issued, which operates an onshore petroleum and/or natural 

gas production facility (as described in §98.230(a)(2). 

Where petroleum and natural gas wells operate without a 

drilling or operating permit, the person or entity that 

pays the State or Federal business income taxes is 

considered the owner or operator.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Operating pressure means the containment pressure that 

characterizes the normal state of gas or liquid inside a 

particular process, pipeline, vessel or tank.

Pump means a device used to raise pressure, drive, or 

increase flow of liquid streams in closed or open conduits.

Pump seals means any seal on a pump drive shaft used 

to keep methane and/or carbon dioxide containing light 

liquids from escaping the inside of a pump case to the 

atmosphere.

Pump seal emissions means hydrocarbon gas released 

from the seal face between the pump internal chamber and 

the atmosphere.

Reservoir means a porous and permeable underground 

natural formation containing significant quantities of 

hydrocarbon liquids and/or gases. 

Residue Gas and Residue Gas Compression mean, 

respectively, production lease natural gas from which gas 

liquid products and, in some cases, non-hydrocarbon 

components have been extracted such that it meets the 

specifications set by a pipeline transmission company, 

and/or a distribution company; and the compressors operated 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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by the processing facility, whether inside the processing 

facility boundary fence or outside the fence-line, that 

deliver the residue gas from the processing facility to a 

transmission pipeline.

Separator means a vessel in which streams of multiple 

phases are gravity separated into individual streams of 

single phase.

Transmission pipeline means high pressure cross 

country pipeline transporting saleable quality natural gas 

from production or natural gas processing to natural gas 

distribution pressure let-down, metering, regulating 

stations where the natural gas is typically odorized before 

delivery to customers.

Turbine meter means a flow meter in which a gas or 

liquid flow rate through the calibrated tube spins a 

turbine from which the spin rate is detected and calibrated 

to measure the fluid flow rate.

Vented emissions means intentional or designed 

releases of CH4 or CO2 containing natural gas or hydrocarbon 

gas (not including stationary combustion flue gas), 

including process designed flow to the atmosphere through 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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seals or vent pipes, equipment blowdown for maintenance, 

and direct venting of gas used to power equipment (such as 

pneumatic devices).

Table W-1A to Subpart W of Part 98--Default Whole Gas 

Emission Factors for Onshore Petroleum and Natural Gas 

Production

Onshore petroleum and natural gas production Emission Factor 

(scf/hour/component)

Eastern U.S.

Population Emission Factors - All Components, 

Gas Service1

Valve 0.027

Connector 0.004

Open-ended Line 0.062

Pressure Relief Valve 0.041

Low Continuous Bleed Pneumatic Device 

Vents2 1.80

High Continuous Bleed Pneumatic Device 

Vents2 48.1

Intermittent Bleed Pneumatic Device Vents2 17.4

Pneumatic Pumps3 13.3

Population Emission Factors - All Components, 

Light Crude Service4

Valve 0.04

Flange 0.002

Connector 0.005

Open-ended Line 0.04

Pump 0.01

Other5 0.23

Population Emission Factors - All Components, 

Heavy Crude Service6

Valve 0.0004

Flange 0.0007

Connector (other) 0.0002

Open-ended Line 0.004

Other5 0.002

Western U.S.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 337 of 520

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Table W-1B to Subpart W of Part 98--Default Average 

Component Counts for Major Onshore Natural Gas Production 

Equipment

Major Equipment Valves Connectors Open-ended Pressure 

Population Emission Factors - All Components, 

Gas Service1

Valve 0.123

Connector 0.017

Open-ended Line 0.032

Pressure Relief Valve 0.196

Low Continuous Bleed Pneumatic Device 

Vents2 1.80

High Continuous Bleed Pneumatic Device 

Vents2 48.1

Intermittent Bleed Pneumatic Device Vents2 17.4

Pneumatic Pumps3 13.3

Population Emission Factors - All Components, 

Light Crude Service4

Valve 0.04

Flange 0.002

Connector (other) 0.005

Open-ended Line 0.04

Pump 0.01

Other5 0.23

Population Emission Factors - All Components, 

Heavy Crude Service6

Valve 0.0004

Flange 0.0007

Connector (other) 0.0002

Open-ended Line 0.004

Other5 0.002

1 For multi-phase flow that includes gas, use the gas service emissions 

factors

2 Emission Factor is in units of "scf/hour/device"

3 Emission Factor is in units of "scf/hour/pump"

4 Hydrocarbon liquids greater than or equal to 20 ̊API are considered 

"light crude"

5 ”Others” category includes instruments, loading arms, pressure relief 

valves, stuffing boxes, compressor seals, dump lever arms, and vents.

6 Hydrocarbon liquids less than 20 ̊API are considered "heavy crude"
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 338 of 520

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Lines relief

valves

Eastern U.S.

Wellheads 8 38 0.5 0

Separators 1 6 0 0

meters/piping 12 45 0 0

Compressors 12 57 0 0

In-line heaters 14 65 2 1

Dehydrators 24 90 2 2

Western U.S.

Wellheads 11 36 1 0

Separators 34 106 6 2

meters/piping 14 51 1 1

Compressors 73 179 3 4

In-line heaters 14 65 2 1

Dehydrators 24 90 2 2

Table W-1C to Subpart W of Part 98--Default Average 

Component Counts For Major Crude Oil Production Equipment

Major Equipment Valves Flanges Connecto

rs

Openended 

Lines

Other 

Components

Eastern U.S.

Wellhead 5 10 4 0 1

Separator 6 12 10 0 0

Heater-treater 8 12 20 0 0

Header 5 10 4 0 0

Western U.S.

Wellhead 5 10 4 0 1

Separator 6 12 10 0 0

Heater-treater 8 12 20 0 0

Header 5 10 4 0 0
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 339 of 520

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Table W-1D of Subpart W of Part 98--Designation Of Eastern 

And Western U.S.

Eastern U.S. Western U.S.

Connecticut Alabama

Delaware Alaska

Florida Arizona

Georgia Arkansas

Illinois California

Indiana Colorado

Kentucky Hawaii

Maine Idaho

Maryland Iowa

Massachusetts Kansas

Michigan Louisiana

New Hampshire Minnesota

New Jersey Mississippi

New York Missouri

North Carolina Montana

Ohio Nebraska

Pennsylvania Nevada

Rhode Island New Mexico

South Carolina North Dakota

Tennessee Oklahoma

Vermont Oregon

Virginia South Dakota

West Virginia Texas

Wisconsin Utah

Washington

Wyoming

Table W-2 to Subpart W of Part 98--Default Total 

Hydrocarbon Emission Factors for Onshore Natural Gas 

Processing 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Onshore natural gas processing Emission Factor 

(scf/hour/component)

Leaker Emission Factors - Compressor Components, Gas Service

Valve1 15.07

Connector 5.68

Open-Ended Line 17.54

Pressure Relief Valve 40.27

Meter 19.63

Leaker Emission Factors – Non-Compressor Components, Gas Service

Valve 6.52

Connector 5.80

Open-Ended Line 11.44

Pressure Relief Valve 2.04

Meter 2.98

1 Valves include control valves, block valves and regulator valves.

Table W-3 to Subpart W of Part 98--Default Total 

Hydrocarbon Emission Factors for Onshore Natural Gas 

Transmission Compression

Onshore natural gas transmission 

compression

Emission Factor 

(scf/hour/component)

Leaker Emission Factors - Compressor Components, Gas Service

Valve1 15.07

Connector 5.68

Open-Ended Line 17.54

Pressure Relief Valve 40.27

Meter 19.63

Leaker Emission Factors – Non-Compressor Components, Gas Service

Valve1 6.52

Connector 5.80
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 341 of 520

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Open-Ended Line 11.44

Pressure Relief Valve 2.04

Meter 2.98

Population Emission Factors – Gas Service

Low Continuous Bleed Pneumatic Device 

Vents2 1.79

High Continuous Bleed Pneumatic Device 

Vents2 20.1

Intermittent Bleed Pneumatic Device 

Vents2 20.1

1 Valves include control valves, block valves and regulator valves.

2 Emission Factor is in units of "scf/hour/device"

Table W-4 to Subpart W of Part 98—Default Total Hydrocarbon 

Emission Factors for Underground Natural Gas Storage

Underground natural gas storage

Emission Factor 

(scf/hour/componen

t)

Leaker Emission Factors - Storage Station, Gas Service

Valve1 15.07 

Connector 5.68 

Open-Ended Line 17.54 

Pressure Relief Valve 40.27 

Meter 19.63

Population Emission Factors - Storage Wellheads, Gas Service

Connector 0.01 

Valve 0.10

Pressure Relief Valve 0.17

Open-ended Line 0.03

Population Emission Factors - Other Components, Gas Service

Low Continuous Bleed Pneumatic Device Vents2 1.79

High Continuous Bleed Pneumatic Device Vents2 20.1

Intermittent Bleed Pneumatic Device Vents2

20.1

1 Valves include control valves, block valves and regulator valves.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 342 of 520

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Underground natural gas storage

Emission Factor 

(scf/hour/componen

t)

Leaker Emission Factors - Storage Station, Gas Service

2 Emission Factor is in units of "scf/hour/device"

Table W-5 to Subpart W of Part 98—Default Methane Emission 

Factors for Liquefied Natural Gas (LNG) Storage

LNG Storage

Emission Factor 

(scf/hour/compon

ent)

Leaker Emission Factors - LNG Storage Components, LNG Service

Valve 1.21

Pump Seal 4.06

Connector 0.35

Other1 1.80

Population Emission Factors - LNG Storage Compressor, Gas Service

Vapor Recovery Compressor2 4.23

1 "other" equipment type should be applied for any equipment type other 

than connectors, pumps, or valves.

2 Emission Factor is in units of "scf/hour/compressor"

Table W-6 to Subpart W of Part 98—Default Methane Emission 

Factors for LNG Import and Export Equipment

LNG import and export equipment

Emission Factor 

(scf/hour/compone

nt)

Leaker Emission Factors - LNG Terminals Components, LNG Service

Valve 1.21

Pump Seal 4.06

Connector 0.35
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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LNG import and export equipment

Emission Factor 

(scf/hour/compone

nt)

Other1 1.80

Population Emission Factors - LNG Terminals Compressor, Gas Service

Vapor Recovery Compressor2 4.23

1 "other" equipment type should be applied for any equipment type other 

than connectors, pumps, or valves.

2 Emission Factor is in units of "scf/hour/compressor"

Table W-7 to Subpart W of Part 98—Default Methane Emission 

Factors for Natural Gas Distribution

Natural gas distribution Emission Factor 

(scf/hour/component)

Leaker Emission Factors - Above Grade M&R at City Gate Stations1

Components, Gas Service

Connector 1.72

Block Valve 0.566

Control Valve 9.48

Pressure Relief Valve 0.274

Orifice Meter 0.215

Regulator 0.784

Open-ended Line 26.533

Population Emission Factors - Below Grade M&R2 Components, Gas Service3

Below Grade M&R Station, Inlet Pressure > 300 

psig 1.32

Below Grade M&R Station, Inlet Pressure 100 to 

300 psig 0.20

Below Grade M&R Station, Inlet Pressure < 100 

psig 0.10

Population Emission Factors - Distribution Mains, Gas Service4

Unprotected Steel 12.77

Protected Steel 0.36

Plastic 1.15

Cast Iron 27.67

Population Emission Factors - Distribution Services, Gas Service5

Unprotected Steel 0.19

Protected Steel 0.02
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 344 of 520

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Natural gas distribution Emission Factor 

(scf/hour/component)

Plastic 0.001

Copper 0.03

1 City gate stations at custody transfer and excluding customer meters

2 Excluding customer meters

3 Emission Factor is in units of "scf/hour/station"

4 Emission Factor is in units of "scf/hour/mile"

5 Emission Factor is in units of “scf/hour/number of services”

Subpart FF – Underground Coal Mines

§98.320 Definition of the source category.

(a) This source category consists of active 

underground coal mines, and any underground mines under 

development that have operational pre-mining degasification 

systems. An underground coal mine is a mine at which coal 

is produced by tunneling into the earth to the coalbed, 

which is then mined with underground mining equipment such 

as cutting machines and continuous, longwall, and shortwall 

mining machines, and transported to the surface. 

Underground coal mines are categorized as active if any one 

of the following five conditions apply:

(1) Mine development is underway.

(2) Coal has been produced within the last 90 days.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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(3) Mine personnel are present in the mine workings.

(4) Mine ventilation fans are operative.

(5) The mine is designated as an ”intermittent” mine

by the Mine Safety and Health Administration (MSHA). 

(b) This source category includes the following: 

(1) Each ventilation well or shaft, including both 

those wells and shafts where gas is emitted and those where 

gas is sold, used onsite, or otherwise destroyed (including 

by flaring). 

(2) Each degasification system well or shaft, 

including degasification systems deployed before, during, 

or after mining operations are conducted in a mine area.

This includes both those wells and shafts where gas is 

emitted, and those where gas is sold, used onsite, or 

otherwise destroyed (including by flaring). 

(c) This source category does not include abandoned

or closed mines, surface coal mines, or post-coal mining 

activities (e.g., storage or transportation of coal).

§98.321 Reporting threshold.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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You must report GHG emissions under this subpart if 

your facility contains an active underground coal mine and 

the facility meets the requirements of §98.2(a)(1).

§98.322 GHGs to report.

(a) You must report CH4 liberated from ventilation and 

degasification systems. 

(b) You must report CH4 destruction from systems where 

gas is sold, used onsite, or otherwise destroyed (including 

by flaring). 

(c) You must report net CH4 emissions from ventilation 

and degasification systems. 

(d) You must report under this subpart the CO2

emissions from coal mine gas CH4 destruction occuring at the 

facility, where the gas is not a fuel input for energy 

generation or use (e.g., flaring).

(e) You must report under subpart C of this part 

(General Stationary Fuel Combustion Sources) the CO2, CH4, 

and N2O emissions from each stationary fuel combustion unit 

by following the requirements of subpart C. Report 

emissions from both the combustion of collected coal mine 

CH4 and any other fuels. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(f) An underground coal mine that is subject to this 

part because emissions from source categories described in 

Tables A-3, A-4 or A-5, or from stationary combustion 

(subpart C), is not required to report emissions under 

subpart FF of this part unless the coal mine liberates 

36,500,000 actual (acf) or more of methane per year from 

its ventilation system.

§98.323 Calculating GHG emissions.

(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 FF1 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.



















1,000

0.454

*1,440 *

1 atm

P

*

T

520 R

* 0.0423*

100%

C

CH n* V*

4V



MCF * (Eq. FF-1)

Where:

CH4V = Quarterly CH4 liberated from a ventilation 

monitoring point (metric tons CH4).

V = Volumetric flow rate for the quarter
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Page 348 of 520

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(cfm) based on sampling or a flow rate 

meter. If a flow rate meter is used and 

the meter automatically corrects for 

temperature and pressure, 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)n 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 methane 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 monitoring point.

0.0423 = Density of CH4 at 520°R (60°F) and 1 atm 

(lb/scf).

520 oR = 520 degrees Rankine.

T = Temperature at which flow is measured (°R)

for the quarter.

P = 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).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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0.454/1,000 = Conversion factor (metric ton/lb). 

(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 continous measurements are taken, then use the 

average value over the time period of continuous 

monitoring.

(3) If a facility has more than one monitoring point, 

the facility must calculate total CH4 liberated from 

ventilation systems (CH4vTotal) as the sum of the CH4 from all 

ventilation monitoring points in the mine, as follows:





m

i

CH V i

1

4VTotal 4 CH ( ) (Eq. FF-2)

Where:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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CH4VTotal = Total quarterly CH4 liberated from ventilation 

systems (metric tons CH4).

CH4V = Quarterly CH4 liberated from each ventilation 

monitoring point (metric tons CH4).

m = Number of ventilation monitoring points.

(b) For each monitoring point in the degasification 

system (this could be at each degasification well and/or 

vent hole, or at more centralized points into which CH4 from 

multiple wells and/or vent holes are collected), you must 

calculate the weekly CH4 liberated from the mine using CH4

measured weekly or more frequently (including by CEMS) 

according to 98.234(c), CH4 content, flow rate, temperature, 

pressure, and moisture content, and Equation FF-3 of this 

section.

















  1,000

0.454 *1,440 *

1 atm

P

*

T

520 R

*0.0423 *

100%

C

CH V *MCF *

i

i

o

i

i i

1

4D

n

i

(Eq. FF-3)

Where:

CH4D = Weekly CH4 liberated from at the 

monitoring point(metric tons CH4).

Vi = Measured volumetric flow rate for the days 

in the week when the degasification system 

is in operation at that monitoring point, 

based on sampling or a flow rate meter 

(cfm).If a flow rate meter is used and the 

meter automatically corrects for 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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temperature and pressure, replace 

“520°R/Ti × Pi/1 atm” with “1”.

MCFi = Moisture correction factor for the 

measurement period, volumetric basis. 

= 1 when Vi and Ci are measured on a dry 

basis or if both are measured on a wet 

basis.

= 1-(fH2O)i when Vi is measured on a wet 

basis and Ci is measured on a dry basis.

= 1/[1-(fH2O)i] when Vi is measured on a dry 

basis and Ci 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) 

Ci = CH4 concentration of gas for the days in 

the week when the degasification system is 

in operation at that monitoring point (%).

n = The number of days in the week that the 

system is operational at that measurement 

point. 

0.0423 = Density of CH4 at 520°R (60°F) and 1 atm 

(lb/scf). 

520 oR = 520 degrees Rankine.

Ti = Temperature at which flow is measured

(°R). 

Pi = Pressure at which flow is measured (atm).

1,440 = Conversion factor (minutes/day). 

0.454/1,000 = Conversion factor (metric ton/lb).

(1) Values for V, C, T, P, and fH2O, if applicable,

must be based on measurements taken at least once each 

calendar week with at least 3 days between measurements. 

If measurements are taken more frequently than once per 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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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:

   D i j

w

j

m

i

CH 4 ,

1 1

CH4DTotal     (Eq. FF-4)

Where:

CH4DTotal = Quarterly CH4 liberated from all degasification

monitoring points (metric tons CH4).

CH4D = Weekly CH4 liberated from a degasification

monitoring point (metric tons CH4).

m = Number of monitoring points.

w = Number of weeks in the quarter during which the 

degasification system is operated.

(c) If gas from degasification system wells or 

ventilation shafts is sold, used onsite, or otherwise 

destroyed (including by flaring), you must calculate the 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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quarterly CH4 destroyed for each destruction device and each 

point of offsite transport to a destruction device, using 

Equation FF-5 of this section. You must measure CH4 content 

and flow rate according to the provisions in §98.324, and 

calculate the methane routed to the destruction device 

(CH4) using either Eq. FF-1 or Eq. FF-3, as applicable.

CH4Destroyed = CH4 x DE (Eq. FF-5)

Where:

CH4Destroyed = Quarterly CH4 destroyed (metric tons). 

CH4 = Quarterly CH4 routed to the destruction

device or offsite transfer point (metric 

tons). 

DE = Destruction efficiency (lesser of 

manufacturer’s specified destruction 

efficiency and 0.99). If the gas is 

transported off-site for destruction, use 

DE = 1.

(1) Calculate total CH4 destroyed as the sum of the 

methane destroyed at all destruction devices (onsite and 

offsite), using Equation FF-6 of this section.

  Destroyed d

d

i

CH4

1

CH4Destroyed Total  (Eq. FF-6)

Where:
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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CH4DestroyedTotal = Quarterly total CH4 destroyed at the mine 

(metric tons CH4).

CH4Destroyed = Quarterly CH4 destroyed from each 

destruction device or offsite transfer 

point.

d = Number of onsite destruction devices and 

points of ofsite transport.

(d) You must calculate the quarterly measured net CH4

emissions to the atmosphere using Equation FF-7 of this 

section.

CH4 emitted (net) = CH4VTotal + CH4DTotal – CH4destroyedTotal(Eq. FF-7)

Where: 

CH4 emitted (net)= Quarterly CH4 emissions from the mine

(metric tons).

CH4VTotal = Quarterly sum of the CH4 liberated from 

all mine ventilation monitoring points 

(CH4V), calculated using Equation FF-2

of this section (metric tons).

CH4DTotal = Quarterly sum of the CH4 liberated from 

all mine degasification monitoring 

points(CH4D), calculated using Equation 

FF-4 of this section (metric tons).

CH4DestroyedTotal = Quarterly sum of the measured CH4

destroyed from all mine ventilation and 

degasification systems, calculated 

using Equation FF-6 of this section 

(metric tons).
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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(e) For the methane collected from degasification 

and/or ventilation systems that is destroyed on site and is 

not a fuel input for energy generation or use (those 

emissions are monitored and reported under Subpart C of 

this part), you must estimate the CO2 emissions using 

Equation FF-8 of this section. 

CO2 = CH4Destroyedonsite * 44/16 (Eq. FF-8)

Where:

CO2 = Total quarterly CO2 emissions from CH4

destruction (metric tons).

CH4Destroyedonsite = Quarterly sum of the CH4 destroyed,

calculated as the sum of CH4 destroyed 

for each onsite, non-energy use, as 

calculated individually in Equation FF5 of this section (metric tons).

44/16 = Ratio of molecular weights of CO2 to 

CH4.

§98.324 Monitoring and QA/QC requirements. 

(a) For calendar year 2011 monitoring, the facility 

may submit a request to the Administrator to use one or 

more best available monitoring methods as listed in 

§98.3(d)(1)(i) through (iv). The request must be submitted 

no later than [INSERT DATE 90 DAYS AFTER PUBLICATION IN THE 

FEDERAL REGISTER] and must contain the information in 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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§98.3(d)(2)(ii). To obtain approval, the request must 

demonstrate to the Administrator’s satisfaction that it is 

not reasonably feasible to acquire, install, and operate a 

required piece of monitoring equipment by January 1, 2011. 

The use of best available monitoring methods will not be 

approved beyond December 31, 2011. 

(b) For CH4 liberated from ventilation systems, 

determine whether CH4 will be monitored from each 

ventilation well and shaft, from a centralized monitoring 

point, or from a combination of the two options. Operators 

are allowed flexibility for aggregating emissions from more 

than one ventilation well or shaft, as long as emissions 

from all are addressed, and the methodology for calculating 

total emissions documented. Monitor by one of the 

following options: 

(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 MSHA inspection samples are taken, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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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. 

(2) Obtain results of the quarterly (or more 

frequent) testing performed by MSHA for the methane 

flowrate. At the time and location of the MSHA sampling, 

make measurements of temperature, pressure and moisture 

content using the same procedures specified in paragraph 

(b)(1) of this section. 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.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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(3) Monitor emissions through the use of one or more 

continuous emission monitoring systems (CEMS). If 

operators use CEMS as the basis for emissions reporting, 

they must provide documentation on the process for using 

data obtained from their CEMS to estimate emissions from 

their mine ventilation systems.

(c) For CH4 liberated at degasification systems, 

determine whether CH4 will be monitored from each well and 

gob gas vent hole, from a centralized monitoring point, or 

from a combination of the two options. Operators are 

allowed flexibility for aggregating emissions from more 

than one well or gob gas vent hole, as long as emissions 

from all are addressed, and the methodology for calculating 

total emissions is documented. Monitor both gas volume and 

methane concentration by one of the following two options: 

(1) Monitor emissions through the use of one or more 

continuous emissions monitoring systems (CEMS). If 

operators use CEMS as the basis for emissions reporting, 

they must provide documentation on the process for using 

data obtained from their CEMS to estimate emissions from 

their mine ventilation systems.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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(2) Collect weekly (once each calendar week, with at 

least three days between measurements) or more frequent 

samples, for all degasification wells and gob gas vent 

holes. Determine weekly or more frequent flow rates,

methane concentration, temperature, and pressure from these 

degasification wells and gob gas vent holes. Methane 

composition should be determined either by submitting 

samples to a lab for analysis, or from the use of 

methanometers at the degasification well site. Follow the 

sampling protocols for sampling of methane emissions from 

ventilation shafts, as described in §98.324(b)(1). 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. 

(3) If the CH4 concentration is determined on a dry 

basis and flow is determined on a wet basis or CH4

concentration is determined on a wet basis and flow is 

determined on a dry basis, and the flow meter does not 

automatically correct for moisture content, determine the 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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moisture content in the gas in a location near or 

representative of the location of:

(i) The gas flow meter at least once each calendar 

week; if measuring with CEMS. If only one measurement is 

made each calendar week, there must be at least three days 

between measurements; and 

(ii) The grab sample, if using grab samples, at the 

time of the sample.

(d) Monitoring must adhere to one of the methods 

specified in paragraphs (d)(1) through (d)(2) of this 

section.

(1) ASTM D1945-03, Standard Test Method for Analysis

of Natural Gas by Gas Chromatography; ASTM D1946-90 

(Reapproved 2006), Standard Practice for Analysis of 

Reformed Gas by Gas Chromatography; ASTM D4891-89 

(Reapproved 2006), Standard Test Method for Heating Value 

of Gases in Natural Gas Range by Stoichiometric Combustion; 

or ASTM UOP539-97 Refinery Gas Analysis by Gas 

Chromatography (incorporated by reference, see §98.7).

(2) As an alternative to the gas chromatography 

methods provided in paragraph (d)(1) of this section, you 
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not provide legal advice, have legally binding effect, or 

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rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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may use gaseous organic concentration analyzers and a 

correction factor to calculate the CH4 concentration 

following the requirements in paragraphs (d)(2)(i) through 

(d)(2)(iii) of this section.

(i) Use Method 25A or 25B at 40 CFR part 60, appendix A-7 

to determine gaseous organic concentration as required in 

§98.323 and in paragraphs (b) and (c) of this section. You 

must calibrate the instrument with CH4 and determine the 

total gaseous organic concentration as carbon (or as CH4; 

K=1 in Equation 25A-1 of Method 25A at 40 CFR part 60, 

appendix A-7).

(ii) Determine a correction factor that will be used with 

the gaseoue organic concentrations measured in paragraph 

(i) of this section. The correction factor must be 

determined at the routine sampling location no less 

frequently than once a reporting year following the 

requirements in paragraphs (d)(2)(ii)(A) through 

(d)(2)(ii)(C) of this section.

(A) Take a minimum of three grab samples of the gas with a 

minimum of 20 minutes between samples and determine the 
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methane composition of the gas using one of the methods 

specified in paragraph (d)(1) of this section.

(B) As soon as practical after each grab sample is 

collected and prior to the collection of a subsequent grab 

sample, determine the gaseous organic concentration of the 

gas using either Method 25A or 25B at 40 CFR part 60, 

appendix A-7 as specified in paragraph (d)(2)(i) of this 

section.

(C) Determine the arithmetic average methane concentration 

and the arithmetic average gaseous organic concentration of 

the samples analyzed according to paragraphs (d)(2)(ii)(A) 

and (d)(2)(ii)(B) of this section, respectively, and 

calculate the non-methane organic carbon correction factor 

as the ratio of the average methane concentration to the 

average total gaseous organic concentration. If the ratio 

exceeds 1, use 1 for the correction factor.

(iii) Calculate the CH4 concentration as specified in 

Equation FF-9 of this section.

CCH4 = fNMOC x CTGOC (Eq. FF-9)

Where:
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CCH4 = Methane (CH4) concentration in the gas(volume %) 

for use in Equations FF-1 and FF-3 of this subpart.

fNMOC = Correction factor from the most recent 

determination of the correction factor as specified in 

paragraph (d)(2)(ii) of this section (unitless).

CTGOC = Gaseous organic carbon concentration measured 

using Method 25A or 25B at 40 CFR part 60, appendix A-7 

during routine monitoring of the gas (volume %).

(e) All flow meters and gas composition monitors that 

are used to provide data for the GHG emissions calculations

shall be calibrated prior to the first reporting year, 

using the applicable methods specified in paragraphs (d) 

and (e)(1) through (e)(7) of this section. Alternatively, 

calibration procedures specified by the flow meter

manufacturer may be used. Flow meters and gas composition 

monitors shall be recalibrated either annually or at the

minimum frequency specified by the manufacturer The 

operator shall operate, maintain, and calibrate a gas 

composition monitor capable of measuring the concentration

of CH4 in the gas using one of the methods specified in
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paragraph (d) of this section. The operator shall operate,

maintain, and calibrate the flow meter using any of the 

following test methods or follow the procedures specified 

bythe flow meter manufacturer. Flow meters must meet the 

accuracy requirements in §98.3(i).

(1) ASME MFC–3M–2004, Measurement of Fluid Flow in 

Pipes Using Orifice, Nozzle, and Venturi (incorporated by 

reference, see §98.7).

(2) ASME MFC–4M–1986 (Reaffirmed 1997), Measurement 

of Gas Flow by Turbine Meters (incorporated by reference, 

see §98.7).

(3) ASME MFC–6M–1998, Measurement of Fluid Flow in 

Pipes Using Vortex Flowmeters (incorporated by reference, 

see §98.7).

(4) ASME MFC–7M–1987 (Reaffirmed 1992), Measurement 

of Gas Flow by Means of Critical Flow Venturi Nozzles 

(incorporated by reference, see §98.7).

(5) ASME MFC-11M-2006 Measurement of Fluid Flow by 

Means of Coriolis Mass Flowmeters (incorporated by 

reference, see §98.7).
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not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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(6) ASME MFC-14M-2003 Measurement of Fluid Flow Using 

Small Bore Precision Orifice Meters (incorporated by 

reference, see §98.7).

(7) ASME MFC-18M-2001 Measurement of Fluid Flow using 

Variable Area Meters (incorporated by reference, see 

§98.7).

(f) For CH4 destruction, CH4 must be monitored at each 

onsite destruction device and each point of offsite 

transport for combustion using continuous monitors of gas 

routed to the device or point of offsite transport.

(g) All temperature, pressure, and moisture content

monitors must be operated and calibrated using the 

procedures and frequencies specified by the manufacturer. 

(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.
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not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

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in regard to any person. The purpose of this redline is to 

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§98.325 Procedures for estimating missing data.

(a) A complete record of all measured parameters used 

in the GHG emissions calculations is required. Therefore, 

whenever a quality-assured value of a required parameter is 

unavailable (e.g., if a meter malfunctions during unit 

operation or if a required fuel sample is not taken), a 

substitute data value for the missing parameter shall be 

used in the calculations, in accordance with paragraph (b) 

of this section.

(b) For each missing value of CH4 concentration, flow 

rate, temperature, pressure, and moisture content for 

ventilation and degasification systems, the substitute data 

value shall be the arithmetic average of the qualityassured values of that parameter immediately preceding and 

immediately following the missing data incident. If, for a 

particular parameter, no quality-assured data are available 

prior to the missing data incident, the substitute data 

value shall be the first quality-assured value obtained 

after the missing data period.

§98.326 Data reporting requirements. 
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In addition to the information required by §98.3(c), 

each annual report must contain the following information 

for each mine: 

(a) Quarterly CH4 liberated from each ventilation 

monitoring point (CH4Vm), (metric tons CH4).

(b) Weekly CH4 liberated from each degasification 

system monitoring point (metric tons CH4).

(c) Quarterly CH4 destruction at each ventilation and 

degasification system destruction device or point of 

offsite transport (metric tons CH4).

(d) Quarterly CH4 emissions (net) from all ventilation 

and degasification systems (metric tons CH4).

(e) Quarterly CO2 emissions from on-site destruction 

of coal mine gas CH4, where the gas is not a fuel input for 

energy generation or use (e.g., flaring) (metric tons CO2).

(f) Quarterly volumetric flow rate for each

ventilation monitoring point (scfm), date and location of

each measurement, and method of measurement (quarterly 

sampling or continuous monitoring, used in Equation FF-1.

(g) Quarterly CH4 concentration for each ventilation 

monitoring point, dates and locations of each measurement
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and method of measurement (sampling or continuous 

monitoring).

(h) Weekly volumetric flow rate used to calculate CH4

liberated from degasification systems (cfm) and method of 

measurement (sampling or continuous monitoring), used in 

Equation FF-3.

(i) Quarterly CEMS CH4 concentration (%) used to 

calculate CH4 liberated from degasification systems (average 

from daily data), or quarterly CH4 concentration data based 

on results from weekly sampling data)(C).

(j) Weekly volumetric flow rate used to calculate CH4

destruction for each destruction device and each point of 

offsite transport (cfm).

(k) Weekly CH4 concentration (%) used to calculate CH4

flow to each destruction device and each point of offsite 

transport (C).

(l) Dates in quarterly reporting period where active 

ventilation of mining operations is taking place.

(m) Dates in quarterly reporting period where 

degasification of mining operations is taking place.
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in regard to any person. The purpose of this redline is to 

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(n) Dates in quarterly reporting period when 

continuous monitoring equipment is not properly 

functioning, if applicable.

(o) Temperatures (°R), pressure (atm), and moisture 

content used in Eq. FF-1 and FF-3, and the gaseous organic 

concentration correction factor, if Equation FF-9 was 

required.

(p) For each destruction device, a description of the 

device, including an indication of whether destruction 

occurs at the coal mine or off-site. If destruction occurs 

at the mine, also report an indication of whether a back-up 

destruction device is present at the mine, the annual 

operating hours for the primary destruction device, the 

annual operating hours for the back-up destruction device 

(if present), and the destruction efficiencies assumed

(percent). 

(q) A description of the gas collection system 

(manufacturer, capacity, and number of wells) the surface 

area of the gas collection system (square meters), and the 

annual operating hours of the gas collection system. 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

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rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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(r) Identification information and description for 

each well and shaft, indication of whether the well or 

shaft is monitored individually, or as part of a 

centralized monitoring point. Note which method (sampling 

or continuous monitoring) was used. 

(s) For each centralized monitoring point, 

identification of the wells and shafts included in the 

point. Note which method (sampling or continuous 

monitoring) was used. 

§98.327 Records that must be retained.

In addition to the information required by §98.3(g), 

you must retain the following records:

(a) Calibration records for all monitoring equipment, 

including the method or manufacturer’s specification used 

for calibration.

(b) Records of gas sales. 

(c) Logbooks of parameter measurements. 

(d) Laboratory analyses of samples.

§98.328 Definitions.

All terms used in this subpart have the same meaning 

given in the Clean Air Act and subpart A of this part. 
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in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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Subpart II – Industrial Wastewater Treatment

§98.350 Definition of Source Category

(a) This source category consists of anaerobic 

processes used to treat industrial wastewater and 

industrial wastewater treatment sludge at facilities that 

perform the operations listed in this paragraph.

(1) Pulp and paper manufacturing.

(2) Food processing.

(3) Ethanol production.

(4) Petroleum refining.

(b) An anaerobic process is a procedure in which 

organic matter in wastewater, wastewater treatment sludge, 

or other material is degraded by micro-organisms in the 

absence of oxygen, resulting in the generation of CO2 and 

CH4. This source category consists of the following: 

anaerobic reactors, anaerobic lagoons, anaerobic sludge 

digesters, and biogas destruction devices (for example, 

burners, boilers, turbines, flares, or other devices). 
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(1) An anaerobic reactor is an enclosed vessel used 

for anaerobic wastewater treatment (e.g., upflow anaerobic 

sludge blanket, fixed film).

(2) An anaerobic sludge digester is an enclosed vessel 

in which wastewater treatment sludge is degraded 

anaerobically.

(3) An anaerobic lagoon is a lined or unlined earthen 

basin used for wastewater treatment, in which oxygen is 

absent throughout the depth of the basin, except for a 

shallow surface zone. Anaerobic lagoons are not equipped 

with surface aerators. Anaerobic lagoons are classified as 

deep (depth more than 2 meters) or shallow (depth less than 

2 meters).

(c) This source category does not include municipal

wastewater treatment plants or separate treatment of 

sanitary wastewater at industrial sites.

§98.351 Reporting threshold.

You must report GHG emissions under this subpart if 

your facility meets all of the conditions under paragraphs 

(a) or (b) of this section:
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(a) Petroleum Refineries and Pulp and Paper 

Manufacturing.

(1) The facility is subject to reporting under 

subpart Y of this part (Petroleum Refineries) or subpart AA 

of this part (Pulp and Paper Manufacturing).

(2) The facility meets the requirements of either 

§98.2(a)(1) or (2). 

(3) The facility operates an anaerobic process to 

treat industrial wastewater and/or industrial wastewater 

treatment sludge.

(b) Ethanol Production and Food Processing 

Facilities.

(1) The facility performs an ethanol production or 

food processing operation, as defined in §98.358 of this 

subpart.

(2) The facility meets the requirements of 

§98.2(a)(2). 

(3) The facility operates an anaerobic process to 

treat industrial wastewater and/or industrial wastewater 

treatment sludge.

§98.352 GHGs to report.
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(a) You must report CH4 generation, CH4 emissions, and 

CH4 recovered from treatment of industrial wastewater at 

each anaerobic lagoon and anaerobic reactor.

(b) You must report CH4 emissions and CH4 recovered

from each anaerobic sludge digester.

(c) You must report CH4 emissions and CH4 destruction 

resulting from each biogas collection and biogas 

destruction device. 

(d) You must report under subpart C of this part 

(General Stationary Fuel Combustion Sources) the emissions 

of CO2, CH4, and N2O from each stationary combustion unit 

associated with the biogas destruction device, if present, 

by following the requirements of subpart C of this part. 

§98.353 Calculating GHG emissions.

(a) For each anaerobic reactor and anaerobic lagoon, 

estimate the annual mass of CH4 generated according to the 

applicable requirements in paragraphs (a)(1) through (a)(2)

of this section. 

(1) If you measure the concentration of organic 

material entering the anaerobic reactors or anaerobic 

lagoon using methods for the determination of chemical 
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oxygen demand (COD), then estimate annual mass of CH4

generated using Equation II-1 of this section. 

 



    

52

1

4

0.001

w

CH Gn Floww CODw Bo MCF (Eq. II-1)

Where: 

CH4Gn = Annual mass CH4 generated from the nth anaerobic 

wastewater treatment process (metric tons).

n = Index for processes at the facility, used in 

Equation II-7.

w = Index for weekly measurement period.

Floww = Volume of wastewater sent to an anaerobic 

wastewater treatment process in week w (m3/week), 

measured as specified in §98.354(d).

CODw = Average weekly concentration of chemical oxygen 

demand of wastewater entering an anaerobic 

wastewater treatment process (for week w)(kg/m3), 

measured as specified in §98.354(b) and (c). 

B0 = Maximum CH4 producing potential of wastewater (kg 

CH4/kg COD), use the value 0.25.

MCF = CH4 conversion factor, based on relevant values 

in Table II-1 of this subpart.

0.001 = Conversion factor from kg to metric tons.

(2) If you measure the concentration of organic 

material entering an anaerobic reactor or anaerobic lagoon 

using methods for the determination of 5-day biochemical 

oxygen demand (BOD5), then estimate annual mass of CH4

generated using Equation II-2 of this section. 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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 



    

52

1

4 5,

0.001

w

CH Gn Floww BOD w Bo MCF (Eq. II-2)

Where: 

CH4Gn = Annual mass of CH4 generated from the anaerobic 

wastewater treatment process (metric tons).

n = Index for processes at the facility, used in 

Equation II-7.

w = Index for weekly measurement period.

Floww = Volume of wastewater sent to an anaerobic 

wastewater treatment process in week w(m3/week), 

measured as specified in §98.354(d).

BOD5,w = Average weekly concentration of 5-day 

biochemical oxygen demand of wastewater entering 

an anaerobic wastewater treatment process for 

week w(kg/m3), measured as specified in 

§98.354(b) and (c). 

B0 = Maximum CH4 producing potential of wastewater (kg 

CH4 /kg BOD5), use the value 0.6.

MCF = CH4 conversion factor, based on relevant values 

in Table II-1 of this subpart.

0.001 = Conversion factor from kg to metric tons.

(b) For each anaerobic reactor and anaerobic lagoon 

from which biogas is not recovered, estimate annual CH4

emissions using Equation II-3 of this section. 

CH4En = CH4Gn (Eq. II-3)

Where: 

CH4En = Annual mass of CH4 emissions from the wastewater 

treatment process n from which biogas is not 

recovered (metric tons).
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CH4Gn = Annual mass of CH4 generated from the wastewater 

treatment process n, as calculated in Equation 

II-1 or II-2 of this section(metric tons).

(c) For each anaerobic sludge digester, anaerobic 

reactor, or anaerobic lagoon from which some biogas is 

recovered, estimate the annual mass of CH4 recovered 

according to the requirements in paragraphs (c)(1) and 

(c)(2) of this section. To estimate the annual mass of CH4

recovered, you must continuously monitor biogas flow rate 

and determine the volume of biogas each week and the 

cumulative volume of biogas each year that is collected and 

routed to a destruction device as specified in §98.354(h). 

If the gas flow meter is not equipped with automatic 

correction for temperature, pressure, or, if necessary, 

moisture content, you must determine these parameters as 

specified in paragraph (c)(2)(ii) of this section. 

(1) If you continuously monitor CH4 concentration (and 

if necessary, temperature, pressure, and moisture content 

required as specified in §98.354(f)) of the biogas that is 

collected and routed to a destruction device using a 

monitoring meter specifically for CH4 gas, as specified in 
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not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 379 of 520

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§98.354(g), you must use this monitoring system and 

calculate the quantity of CH4 recovered for destruction 

using Equation II-4 of this section. A fully integrated 

system that directly reports CH4 quantity requires only the

summing of results of all monitoring periods for a given 

year. 

Rn =













 

M

m 1

m

m

CH4 m

m MC m

1,000

0.454

 *

1atm

(P)

 * 

(T)

520R

*0.0423 * 

100%

(C )

(V) *(K ) * (Eq. II-4)

Where:

Rn = Annual quantity of CH4 recovered from the

nth anaerobic reactor, sludge digester, or 

lagoon (metric tons CH4/yr)

n = Index for processes at the facility, used 

in Equation II-7.

M = Total number of measurement periods in a 

year. Use M=365 (M=366 for leap years) for 

daily averaging of continuous monitoring, 

as provided in paragraph(c)(1)of this 

section. Use M=52 for weekly sampling, as 

provided in paragraph(c)(2)of this section.

m = Index for measurement period.

Vm = Cumulative volumetric flow for the 

measurement period in actual cubic 

feet(acf). If no biogas was recovered 

during a monitoring period, use zero.

(KMC)m = Moisture correction term for the 

measurement period, volumetric basis. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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= 1 when (V)m and (CCH4)m are measured on a dry 

basis or if both are measured on a wet 

basis.

= 1-(fH2O)m when (V)m is measured on a wet 

basis and (CCH4)m is measured on a dry basis.

= 1/[1-(fH2O)m] when (V)m is measured on a dry 

basis and (CCH4)m is measured on a wet basis.

(fH2O)m = Average moisture content of biogas during 

the measurment period, volumetric basis, 

(cubic feet water per cubic feet biogas).

(CCH4)m = Average CH4 concentration of biogas during 

the measurement period, (volume %). 

0.0423 = Density of CH4 lb/cf at 520°R or 60°F and 1 

atm. 

520 oR = 520 degrees Rankine.

Tm = Average temperature at which flow is 

measured for the measurement period(°R). If 

the flow rate meter automatically corrects 

for temperature to 520° R, replace “520° 

R/Tm” with “1”.

Pm = Average pressure at which flow is measured 

for the measurement period (atm). If the 

flow rate meter automatically corrects for 

pressure to 1 atm, replace “Pm/1” with “1”.

0.454/1,000 = Conversion factor (metric ton/lb).

(2) If you do not continuously monitor CH4

concentration according to paragraph(c)(1) of this section, 

you must determine the CH4 concentration, temperature, 

pressure, and, if necessary, moisture content of the biogas 

that is collected and routed to a destruction device 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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according to the requirements in paragraphs (c)(2)(i)

through (c)(2)(ii) of this section and calculate the 

quantity of CH4 recovered for destruction using Equation II4 of this section. 

(i) Determine the CH4 concentration in the biogas that 

is collected and routed to a destruction device in a 

location near or representative of the location of the gas 

flow meter at least once each calendar week; if only one 

measurement is made each calendar week, there must be least 

three days between measurements. For a given calendar 

week, you are not required to determine CH4 concentration if 

the cumulative volume of biogas for that calendar week, 

determined as specified in paragraph (c) of this section, 

is zero. 

(ii) If the gas flow meter is not equipped with 

automatic correction for temperature, pressure, or, if 

necessary, moisture content: 

(A) Determine the temperature and pressure in the 

biogas that is collected and routed to a destruction device 

in a location near or representative of the location of the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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gas flow meter at least once each calendar week; if only 

one measurement is made each calendar week, there must be 

at least three days between measurements. 

(B) If the CH4 concentration is determined on a dry 

basis and biogas flow is determined on a wet basis, or CH4

concentration is determined on a wet basis and biogas flow 

is determined on a dry basis, and the flow meter does not 

automatically correct for moisture content, determine the 

moisture content in the biogas that is collected and routed 

to a destruction device in a location near or 

representative of the location of the gas flow meter at 

least once each calendar week that the cumulative biogas 

flow measured as specified in §98.354(h) is greater than 

zero; if only one measurement is made each calendar week, 

there must be at least three days between measurements. 

(d) For each anaerobic sludge digester, anaerobic 

reactor, or anaerobic lagoon from which some quantity of 

biogas is recovered, you must estimate both the annual mass 

of CH4 that is generated, but not recovered, according to 

paragraph (d)(1) of this section and the annual mass of CH4

emitted according to paragraph (d)(2) of this section. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(1) Estimate the annual mass of CH4 that is generated, 

but not recovered, using Equation II-5 of this section. 













  1

CE

1

CH4Ln Rn (Eq. II-5)

Where: 

CH4Ln = Leakage at the anaerobic process n (metric tons

CH4). 

n = Index for processes at the facility, used in 

Equation II-7.

Rn = Annual quantity of CH4 recovered from the nth 

anaerobic reactor, anaerobic lagoon, or 

anaerobic sludge digester, as calculated in 

Equation II-4 of this section (metric tons CH4).

CE = CH4 collection efficiency of anaerobic process n, 

as specified in Table II-2 of this subpart 

(decimal).

(2) For each anaerobic sludge digester, anaerobic 

reactor, or anaerobic lagoon from which some quantity of 

biogas is recovered, estimate the annual mass of CH4 emitted 

using Equation II-6 of this section.

(Eq. II-6)

CH4En = CH4Ln + Rn (1− [ (DE1 ∗ fDest_1 )+ (DE2 ∗ fDest_2)])

Where:

CH4En = Annual quantity of CH4 emitted from the process n 

from which biogas is recovered (metric tons).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 384 of 520

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n = Index for processes at the facility, used in 

Equation II-7.

CH4Ln = Leakage at the anaerobic process n, as calculated 

in Equation II-5 of this section (metric tons 

CH4). 

Rn = Annual quantity of CH4 recovered from the nth 

anaerobic reactor or anaerobic sludge digester, 

as calculated in Equation II-4 of this section 

(metric tons CH4).

DE1 = Primary destruction device CH4 destruction 

efficiency (lesser of manufacturer’s specified 

destruction efficiency and 0.99). If the biogas 

is transported offsite for destruction, use DE=1.

fDest_1 = Fraction of hours the primary destruction device 

was operating (device operating hours/hours in 

the year). If the biogas is transported offsite 

for destruction, use fDest=1.

DE2 = Back-up destruction device CH4 destruction 

efficiency (lesser of manufacturer’s specified 

destruction efficiency and 0.99).

fDest_2 = Fraction of hours the back-up destruction device 

was operating (device operating hours/hours in 

the year). 

(e) Estimate the total mass of CH4 emitted from all 

anaerobic processes from which biogas is not recovered 

(calcluated in Eq. II-3) and all anaerobic processes from 

which some biogas is recovered (calculated in Equation II6) using Equation II-7 of this section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 385 of 520

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



j

n

CH ET CH En

1

4 4 (Eq. II-7)

Where: 

CH4ET = Annual mass CH4 emitted from all anaerobic 

processes at the facility (metric tons).

n = Index for processes at the facility.

CH4En = Annual mass of CH4 emissions from process n 

(metric tons).

j = Total number of processes from which methane is 

emitted. 

§98.354 Monitoring and QA/QC requirements. 

(a) For calendar year 2011 monitoring, the facility 

may submit a request to the Administrator to use one or 

more best available monitoring methods as listed in 

§98.3(d)(1)(i) through (iv). The request must be submitted 

no later than [INSERT DATE 90 DAYS AFTER PUBLICATION IN THE 

FEDERAL REGISTER] and must contain the information in 

§98.3(d)(2)(ii). To obtain approval, the request must 

demonstrate to the Administrator’s satisfaction that it is 

not reasonably feasible to acquire, install, and operate a 

required piece of monitoring equipment by January 1, 2011. 

The use of best available monitoring methods will not be 

approved beyond December 31, 2011. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(b) You must determine the concentration of organic 

material in wastewater treated anaerobically using 

analytical methods for COD or BOD5 specified in 40 CFR part 

136.3 Table 1B. For the purpose of determining 

concentrations of wastewater influent to the anaerobic 

wastewater treatment process, samples may be diluted to the

concentration range of the approved method, but the 

calculated concentration of the undiluted wastewater must 

be used for calcuations and reporting required by this 

subpart.

(c) You must collect samples representing wastewater 

influent to the anaerobic wastewater treatment process,

following all preliminary and primary treatment steps 

(e.g., after grit removal, primary clarfication, oil-water 

separation, dissolved air flotation, or similar solids and 

oil separation processes). You must collect and analyze 

samples for COD or BOD5 concentration at least once each 

calendar week that the anaerobic wastewater treatment 

process is operating; if only one measurement is made each 

calendar week, there must be at least three days between 

measurements. You must collect a sample that represents the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 387 of 520

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average COD or BOD5 concentration of the waste stream over a 

24-hour sampling period. You must collect a minimum of 

four sample aliquots per 24-hour period and composite the 

aliquots for analysis. Collect a flow-proportional 

composite sample (either constant time interval between 

samples with sample volume proportional to stream flow, or 

constant sample volume with time interval between samples 

proportional to stream flow). Follow sampling procedures 

and techniques presented in Chapter 5, Sampling, of the 

“NPDES Compliance Inspection Manual,” (incorporated by 

reference, see §98.7) or Section 7.1.3, Sample Collection 

Methods, of the “U.S. EPA NPDES Permit Writers’ Manual,” 

(incorporated by reference, see §98.7) .

(d) You must measure the flowrate of wastewater 

entering anaerobic wastewater treatment process at least 

once each calendar week that the process is operating; if 

only one measurement is made each calendar week, there must 

be at least three days between measurements. You must 

measure the flowrate for the 24-hour period for which you 

collect samples analyzed for COD or BOD5 concentration. The 

flow measurement location must correspond to the location 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 388 of 520

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used to collect samples analyzed for COD or BOD5

concentration. You must measure the flowrate using one of 

the methods specified in paragraphs (d)(1) through (d)(5) 

of this section or as specified by the manufacturer. 

(1) ASME MFC–3M–2004 Measurement of Fluid Flow in 

Pipes Using Orifice, Nozzle, and Venturi (incorporated by 

reference, see §98.7). 

(2) ASME MFC–5M–1985 (Reaffirmed 1994) Measurement of 

Liquid Flow in Closed Conduits Using Transit-Time 

Ultrasonic Flowmeters (incorporated by reference, see 

§98.7). 

(3) ASME MFC–16–2007 Measurement of Liquid Flow in 

Closed Conduits with Electromagnetic Flowmeters 

(incorporated by reference, see §98.7).

(4) ASTM D1941-91 (Reapproved 2007) Standard Test 

Method for Open Channel Flow Measurement of Water with the 

Parshall Flume, approved June 15, 2007, (incorporated by 

reference, see §98.7).

(5) ASTM D5614-94 (Reapproved 2008) Standard Test 

Method for Open Channel Flow Measurement of Water with 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Broad-Crested Weirs, approved October 1, 2008, 

(incorporated by reference, see §98.7).

(e) All wastewater flow measurement devices must be 

calibrated prior to the first year of reporting and 

recalibrated either biennially (every 2 years) or at the 

minimum frequency specified by the manufacturer. 

Wastewater flow measurement devices must be calibrated 

using the procedures specified by the device manufacturer.

(f) For each anaerobic process (such as anaerobic 

reactor, sludge digester, or lagoon) from which biogas is 

recovered, you must make the measurements or determinations 

specified in paragrahps (f)(1) through(f)(3)of this 

section.

(1) You must continuously measure the biogas flow rate 

as specified in paragraph (h) of this section and determine 

the cumulative volume of biogas recovered. 

(2)You must determine the CH4 concentration of the 

recovered biogas as specified in paragraph (g) of this 

section at a location near or representative of the 

location of the gas flow meter. You must determine CH4

concentration either continuously or intermittently. If 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 390 of 520

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you determine the concentration intermittently, you must 

determine the concentration at least once each calendar 

week that the cumulative biogas flow measured as specified 

in paragraph (h) of this section is greater than zero, with 

at least three days between measurements. 

(3)As specified in §98.353(c) and paragraph (h) of 

this section, you must determine temperature, pressure, and 

moisture content as necessary to accurately determine the 

biogas flow rate and CH4 concentration. You must determine 

temperature and pressure if the gas flow meter or gas 

composition monitor do not automatically correct for 

temperature or pressure. You must measure moisture content 

of the recovered biogas if the biogas flow rate is measured 

on a wet basis and the CH4 concentration is measured on a 

dry basis. You must also measure the moisture content of 

the recovered biogas if the biogas flow rate is measured on 

a dry basis and the CH4 concentration is measured on a wet 

basis. 

(g) For each anaerobic process (such as an anaerobic 

reactor, sludge digester, or lagoon) from which biogas is 

recovered, operate, maintain, and calibrate a gas 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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composition monitor capable of measuring the concentration 

of CH4 in the recovered biogas using one of the methods 

specified in paragraphs (g)(1)through(g)(6) of this section 

or as specified by the manufacturer. 

(1) Method 18 at 40 CFR part 60, appendix A-6.

(2) ASTM D1945-03, Standard Test Method for Analysis 

of Natural Gas by Gas Chromatography (incorporated by 

reference, see §98.7).

(3) ASTM D1946-90 (Reapproved 2006), Standard 

Practice for Analysis of Reformed Gas by Gas Chromatography 

(incorporated by reference, see §98.7).

(4) GPA Standard 2261-00, Analysis for Natural Gas 

and Similar Gaseous Mixtures by Gas Chromatography 

(incorporated by reference, see §98.7).

(5) ASTM UOP539-97 Refinery Gas Analysis by Gas 

Chromatography (incorporated by reference, see §98.7).

(6) As an alternative to the gas chromatography 

methods provided in paragraphs(g)(1) through (g)(5) of this 

section, you may use total gaseous organic concentration 

analyzers and calculate the CH4 concentration following the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 392 of 520

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requirements in paragraphs (g)(6)(i) through (g)(6)(iii) of 

this section.

(i) Use Method 25A or 25B at 40 CFR part 60, appendix 

A-7 to determine total gaseous organic concentration. You 

must calibrate the instrument with CH4 and determine the 

total gaseous organic concentration as carbon (or as CH4; 

K=1 in Equation 25A-1 of Method 25A at 40 CFR part 60, 

appendix A-7).

(ii) Determine a non-methane organic carbon 

correction factor at the routine sampling location no less 

frequently than once a reporting year following the 

requirements in paragraphs (g)(6)(ii)(A) through 

(g)(6)(ii)(C) of this section.

(A) Take a minimum of three grab samples of the 

biogas with a minimum of 20 minutes between samples and 

determine the methane composition of the biogas using one 

of the methods specified in paragraphs (g)(1) through 

(g)(5) of this section.

(B) As soon as practical after each grab sample is 

collected and prior to the collection of a subsequent grab 

sample, determine the total gaseous organic concentration 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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of the biogas using either Method 25A or 25B at 40 CFR part 

60, appendix A-7 as specified in paragraph (g)(6)(i) of 

this section.

(C) Determine the arithmetic average methane 

concentration and the arithmetic average total gaseous 

organic concentration of the samples analyzed according to 

paragraphs (g)(6)(ii)(A) and (g)(6)(ii)(B) of this section, 

respectively, and calculate the non-methane organic carbon 

correction factor as the ratio of the average methane 

concentration to the average total gaseous organic 

concentration. If the ratio exceeds 1, use 1 for the nonmethane organic carbon correction factor.

(iii) Calculate the CH4 concentration as specified in 

Equation II-8 of this section.

CCH4 = fNMOC x CTGOC (Eq. II-8)

Where:

CCH4 = Methane (CH4) concentration in the 

biogas(volume %) for use in Equation II-4 of 

this subpart.

fNMOC = Non-methane organic carbon correction factor 

from the most recent determination of the nonmethane organic carbon correction factor as 

specified in paragraph (g)(6)(ii) of this 

section (unitless).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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CTGOC = Total gaseous organic carbon concentration

measured using Method 25A or 25B at 40 CFR 

part 60, appendix A-7 during routine 

monitoring of the biogas (volume %).

(h) For each anaerobic process (such as an anaerobic 

reactor, sludge digester, or lagoon) from which biogas is 

recovered, install, operate, maintain, and calibrate a gas 

flow meter capable of continuously measuring the volumetric 

flow rate of the recovered biogas using one of the methods 

specified in paragraphs (h)(1) through (h)(8) of this 

section or as specified by the manufacturer. Recalibrate 

each gas flow meter either biennially (every 2 years) or at 

the minimum frequency specified by the manufacturer. 

Except as provided in §98.353(c)(2)(iii), each gas flow 

meter must be capable of correcting for the temperature and 

pressure and, if necessary, moisture content.

(1) ASME MFC-3M-2004, Measurement of Fluid Flow in 

Pipes Using Orifice, Nozzle, and Venturi (incorporated by 

reference, see §98.7).

(2) ASME MFC-4M-1986 (Reaffirmed 1997), Measurement 

of Gas Flow by Turbine Meters (incorporated by reference, 

see §98.7).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(3) ASME MFC-6M-1998, Measurement of Fluid Flow in 

Pipes Using Vortex Flowmeters (incorporated by reference, 

see §98.7).

(4) ASME MFC-7M-1987 (Reaffirmed 1992), Measurement 

of Gas Flow by Means of Critical Flow Venturi Nozzles

(incorporated by reference, see §98.7).

(5) ASME MFC-11M-2006 Measurement of Fluid Flow by 

Means of Coriolis Mass Flowmeters (incorporated by 

reference, see §98.7). The mass flow must be corrected to 

volumetric flow based on the measured temperature, 

pressure, and biogas composition.

(6) ASME MFC-14M-2003 Measurement of Fluid Flow Using 

Small Bore Precision Orifice Meters (incorporated by 

reference, see §98.7).

(7) ASME MFC-18M-2001 Measurement of Fluid Flow using 

Variable Area Meters (incorporated by reference, see 

§98.7).

(8) Method 2A or 2D at 40 CFR part 60, appendix A-1.

(i) All temperature, pressure, and, moisture content

monitors required as specified in paragraph (f) of this 

section must be calibrated using the procedures and 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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frequencies where specified by the device manufacturer, if 

not specified use an industry accepted or industry standard 

practice.

(j) All equipment (temperature, pressure, and 

moisture content monitors and gas flow meters and gas 

composition monitors) must be maintained as specified by 

the manufacturer.

(k) If applicable, the owner or operator must

document the procedures used to ensure the accuracy of 

measurements of COD or BOD5 concentration, wastewater flow 

rate, biogas flow rate, biogas composition, temperature, 

pressure, and moisture content. These procedures include, 

but are not limited to, calibration of gas flow meters, and 

other measurement devices. The estimated accuracy of 

measurements made with these devices must also be recorded, 

and the technical basis for these estimates must be 

documented.

§98.355 Procedures for estimating missing data

A complete record of all measured parameters used in 

the GHG emissions calculations is required. Therefore, 

whenever a quality-assured value of a required parameter is 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 397 of 520

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unavailable (e.g., if a meter malfunctions during unit 

operation or if a required sample is not taken), a 

substitute data value for the missing parameter must be 

used in the calculations, according to the following 

requirements in paragraphs (a) through (c) of this section:

(a) For each missing weekly value of COD or BOD5 or 

wastewater flow entering an anaerobic wastewater treatment 

process, the substitute data value must be the arithmetic 

average of the quality-assured values of those parameters 

for the week immediately preceding and the week immediately 

following the missing data incident. 

(b) For each missing value of the CH4 content or 

biogas flow rates, the substitute data value must be the 

arithmetic average of the quality-assured values of that 

parameter immediately preceding and immediately following 

the missing data incident. 

(c) If, for a particular parameter, no qualityassured data are available prior to the missing data 

incident, the substitute data value must be the first 

quality-assured value obtained after the missing data 

period. If, for a particular parameter, the “after” value 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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is not obtained by the end of the reporting year, you may 

use the last quality-assured value obtained “before” the 

missing data period for the missing data substitution. You 

must document and keep records of the procedures you use 

for all such estimates. 

§98.356 Data reporting requirements. 

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

each annual report must contain the following information 

for each wastewater treatment system. 

(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).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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(3) Anaerobic shallow lagoon (depth less than 2 

meters).

(4) Anaerobic sludge digester.

(b) For each anaerobic wastewater treatment process 

(reactor, deep lagoon, or shallow lagoon) you must report:

(1) Weekly average COD or BOD5 concentration of 

wastewater entering each anaerobic wastewater treatment 

process, for each week the anaerobic process was operated.

(2) Volume of wastewater entering each anaerobic 

wastewater treatment process for each week the anaerobic 

process was operated.

(3) Maximum CH4 production potential (B0) used as an 

input to Equation II-1 or II-2 of this subpart, from Table 

II-1. 

(4) Methane conversion factor (MCF) used as an input 

to Equation II-1 or II-2 of this subpart, from Table II-1.

(5) Annual mass of CH4 generated by each anaerobic 

wastewater treatment process, calculated using Equation II1 or II-2 of this subpart. 

(c) For each anaerobic wastewater treatment process 

from which biogas is not recovered, you must report the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Page 400 of 520

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annual CH4 emissions, calculated using Equation II-3 of this 

subpart. 

(d) For each anaerobic wastewater treatment process 

and anaerobic sludge digester from which some biogas is 

recovered, you must report:

(1) Annual quantity of CH4 recovered from the 

anaerobic process calculated using Equation II-4 of this 

subpart.

(2) Total weekly volumetric biogas flow for each week 

(up to 52 weeks/year) that biogas is collected for 

destruction.

(3) Weekly average CH4 concentration for each week 

that biogas is collected for destruction.

(4) Weekly average biogas temperature for each week 

at which flow is measured for biogas collected for 

destruction, or statement that temperature is incorporated 

into monitoring equipment internal calcultations.

(5) Whether flow was measured on a wet or dry basis, 

whether CH4 concentration was measured on a wet or dry 

basis, and if required for Equation II-4 of this subpart, 

weekly average moisture content for each week at which flow 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 401 of 520

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is measured for biogas collected for destruction, or 

statement that moisture content is incorporated into 

monitoring equipment internal calculations.

(6) Weekly average biogas pressure for each week at 

which flow is measured for biogas collected for 

destruction, or statement that pressure is incorporated 

into monitoring equipment internal calcultations.

(7) CH4 collection efficiency (CE) used in Equation 

II-5 of this subpart.

(8) Whether destruction occurs at the facility or 

offsite. If destruction occurs at the facility, also 

report whether a back-up destruction device is present at 

the facility, the annual operating hours for the primary 

destruction device, the annual operating hours for the 

back-up destruction device (if present), the destruction 

efficiency for the primary destruction device, and the 

destruction efficiency for the back-up destruction device 

(if present).

(9) For each anaerobic process from which some biogas 

is recovered, you must report the annual CH4 emissions, as 

calculated by Equation II-6 of this subpart.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(e) The total mass of CH4 emitted from all anaerobic 

processes from which biogas is not recovered (calcluated in 

Equation II-3 of this supbart) and from all anaerobic 

processes from which some biogas is recovered (calculated 

in Equation II-6 of this subpart) using Equation II-7 of 

this subpart.

§98.357 Records that must be retained. 

In addition to the information required by §98.3(g), 

you must retain the calibration records for all monitoring 

equipment, including the method or manufacturer’s 

specification used for calibration. 

§98.358 Definitions.

Except as provided below, all terms used in this 

subpart have the same meaning given in the CAA and subpart 

A of this part.

Biogas means the combination of CO2, CH4, and other 

gases produced by the biological breakdown of organic 

matter in the absence of oxygen.

Ethanol production means an operation that produces 

ethanol from the fermentation of sugar, starch, grain, or 

cellulosic biomass feedstocks, or the production of ethanol 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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Page 403 of 520

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synthetically from petrochemical feedstocks, such as 

ethylene or other chemicals.

Food processing means an operation used to manufacture 

or process meat, poultry, fruits, and/or vegtables as 

defined under NAICS 3116 (Meat Product Manufacturing) or

NAICS 3114 (Fruit and Vegetable Preserving and Specialty 

Food Manufacturing). For information on NAICS codes, see 

http://www.census.gov/eos/www/naics/.

Industrial wastewater means water containing wastes 

from an industrial process. Industrial wastewater includes 

water which comes into direct contact with or results from 

the storage, production, or use of any raw material, 

intermediate product, finished product, by-product, or 

waste product. Examples of industrial wastewater include, 

but are not limited to, paper mill white water, wastewater 

from equipment cleaning, wastewater from air pollution 

control devices, rinse water, contaminated stormwater, and 

contaminated cooling water. 

Industrial wastewater treatment sludge means solid or 

semi-solid material resulting from the treatment of 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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industrial wastewater, including but not limited to 

biosolids, screenings, grit, scum, and settled solids.

Wastewater treatment system means the collection of 

all processes that treat or remove pollutants and 

contaminants, such as soluble organic matter, suspended 

solids, pathogenic organisms, and chemicals from wastewater 

prior to its reuse or discharge from the facility.

Table II-1 of Subpart II—Emission Factors

Factors Default value Units

B0 – for facilities monitoring 

COD

0.25 Kg CH4/kg COD

B0 – for facilities monitoring 

BOD5

0.60 Kg CH4/kg BOD5

MCF – anaerobic reactor 0.8 Fraction

MCF – anaerobic deep lagoon

(depth more than 2 m)

0.8 Fraction

MCF – anaerobic shallow lagoon 

(depth less than 2 m)

0.2 Fraction

Table II-2 of Subpart II—Collection Efficiencies of 

Anaerobic Processes

Anaerobic Process Type Cover Type

Methane 

Collection 

Efficiency

Covered anaerobic lagoon 

(biogas capture)

Bank to bank, 

impermeable

0.975

Modular, impermeable 0.70

Anaerobic sludge 

digester; anaerobic 

reactor

Enclosed Vessel 0.99
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 405 of 520

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DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 406 of 520

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Subpart OO—Suppliers of Industrial Greenhouse Gases

§ 98.410 Definition of the source category.

(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.

(b) To produce a fluorinated GHG means to manufacture a 

fluorinated GHG from any raw material or feedstock 

chemical. Producing a fluorinated GHG includes the 

manufacture of a fluorinated GHG as an isolated 

intermediate for use in a process that will result in its 

transformation either at or outside of the production 

facility. Producing a fluorinated GHG also includes the 

creation of a fluorinated GHG (with the exception of HFC–

23) that is captured and shipped off site for any reason, 

including destruction. Producing a fluorinated GHG does not 

include the reuse or recycling of a fluorinated GHG, the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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creation of HFC–23 during the production of HCFC–22, the 

creation of intermediates that are created and transformed 

in a single process with no storage of the intermediates, 

or the creation of fluorinated GHGs that are released or 

destroyed at the production facility before the production 

measurement at §98.414(a).

(c) To produce nitrous oxide means to produce nitrous oxide 

by thermally decomposing ammonium nitrate (NH4NO3). 

Producing nitrous oxide does not include the reuse or 

recycling of nitrous oxide or the creation of by-products 

that are released or destroyed at the production facility.

[74 FR 56374, Oct. 30, 2009, as amended at 75 FR 79167, 

Dec. 17, 2010]

§ 98.411 Reporting threshold.

Any supplier of industrial greenhouse gases who meets the 

requirements of §98.2(a)(4) must report GHG emissions.

§ 98.412 GHGs to report.
DRAFT -- This draft only contains redline/strikeout text.

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Draft – Deliberative 

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 d

during the calendar year.

§ 98.413 Calculating GHG emissions.

(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

P = Mass of fluorinated GHG or nitrous oxide produced 

annually.

Pp= Mass of fluorinated GHG or nitrous oxide produced over 

the period “p”.

(b) Calculate the total mass of each fluorinated GHG or 

nitrous oxide produced over th

Equation OO–2 of this section:

This draft only contains redline/strikeout text.

ment is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

ny person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Page 408 of 520

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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 d

during the calendar year.

Calculating GHG emissions.

(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, 

ation OO–1 of this section:

P = Mass of fluorinated GHG or nitrous oxide produced 

= Mass of fluorinated GHG or nitrous oxide produced over 

(b) Calculate the total mass of each fluorinated GHG or 

nitrous oxide produced over the period “p” by using 

2 of this section:

This draft only contains redline/strikeout text. This 

ment is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

ny person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

t Cite, Quote, or Release

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 

(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, 

P = Mass of fluorinated GHG or nitrous oxide produced 

= Mass of fluorinated GHG or nitrous oxide produced over 

(b) Calculate the total mass of each fluorinated GHG or 

e period “p” by using 
DRAFT -- This draft only contains redline/strikeout text.

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Draft – Deliberative 

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 

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).

(c) Calculate the total mass of each fluorinated GHG or 

nitrous oxide transformed by using Equation OO

section:

Where:

This draft only contains redline/strikeout text.

ment is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

ny person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 409 of 520

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= Mass of fluorinated GHG or nitrous oxide produced over 

the period “p” (metric tons).

= Mass of fluorinated GHG or nitrous oxide that is 

measured coming out of the production process over 

period p (metric tons).

= 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).

(c) Calculate the total mass of each fluorinated GHG or 

e transformed by using Equation OO–3 of this 

This draft only contains redline/strikeout text. This 

ment is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

ny person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

t Cite, Quote, or Release

= Mass of fluorinated GHG or nitrous oxide produced over 

= Mass of fluorinated GHG or nitrous oxide that is 

measured coming out of the production process over the 

= Mass of used fluorinated GHG or nitrous oxide that is 

added to the production process upstream of the output 

(c) Calculate the total mass of each fluorinated GHG or 

3 of this 
DRAFT -- This draft only contains redline/strikeout text.

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Draft – Deliberative 

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 

into the transformation process that is transformed in the 

process (metric tons).

(d) Calculate the total mass of each fluorinated GHG 

destroyed by using Equation OO

Where:

D = Mass of fluorinated G

tons).

FD= Mass of fluorinated GHG fed into the destruction device 

annually (metric tons).

This draft only contains redline/strikeout text.

ment is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

ny person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 410 of 520

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T = Mass of fluorinated GHG or nitrous oxide transformed 

annually (metric tons).

= Mass of fluorinated GHG fed into the transformation 

process annually (metric tons).

= The fraction of the fluorinated GHG or nitrous oxide fed 

into the transformation process that is transformed in the 

process (metric tons).

(d) Calculate the total mass of each fluorinated GHG 

destroyed by using Equation OO–4 of this section:

D = Mass of fluorinated GHG destroyed annually (metric 

= Mass of fluorinated GHG fed into the destruction device 

annually (metric tons).

This draft only contains redline/strikeout text. This 

ment is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

ny person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

t Cite, Quote, or Release

T = Mass of fluorinated GHG or nitrous oxide transformed 

= Mass of fluorinated GHG fed into the transformation 

fluorinated GHG or nitrous oxide fed 

into the transformation process that is transformed in the 

(d) Calculate the total mass of each fluorinated GHG 

4 of this section:

HG destroyed annually (metric 

= Mass of fluorinated GHG fed into the destruction device 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Page 411 of 520

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DE = Destruction efficiency of the destruction device 

(fraction).

§ 98.414 Monitoring and QA/QC requirements.

(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 lowconcentration 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.

(b) The mass of any used fluorinated GHGs or used nitrous 

oxide added back into the production process upstream of 
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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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).

(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.

(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 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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Page 413 of 520

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nitrous oxide permanently removed from the process and 

recovered, destroyed, or emitted.

(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.

(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 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.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

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rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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Page 414 of 520

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(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.

(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 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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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.

(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.

(j) [Reserved]

(k) For purposes of Equation OO–4 of this subpart, the 

destruction efficiency can be equated to the destruction 

efficiency determined during a previous performance test of 

the destruction device or, if no performance test has been 

done, the destruction efficiency provided by the 

manufacturer of the destruction device.

(l) In their estimates of the mass of fluorinated GHGs 

destroyed, fluorinated GHG production facilities that 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 416 of 520

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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.

(m) Calibrate all flow meters, weigh scales, and 

combinations of volumetric and density measures that are 

used to measure or calculate quantities that are to be 

reported under this subpart prior to the first year for 

which GHG emissions are reported under this part. 

Calibrations performed prior to the effective date of this 

rule satisfy this requirement. Recalibrate all flow meters, 

weigh scales, and combinations of volumetric and density 

measures at the minimum frequency specified by the 

manufacturer. Use NIST-traceable standards and suitable 

methods published by a consensus standards organization 

(e.g., ASTM, ASME, ISO, or others).

(n) If the mass coming out of the production process 

includes more than one fluorinated GHG, you shall measure 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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the concentrations of all of the fluorinated GHGs, other 

than low-concentration constituents, as follows:

(1) Analytical Methods. Use a quality-assured analytical 

measurement technology capable of detecting the analyte of 

interest at the concentration of interest and use a 

procedure validated with the analyte of interest at the 

concentration of interest. Where standards for the analyte 

are not available, a chemically similar surrogate may be 

used. Acceptable analytical measurement technologies 

include but are not limited to gas chromatography (GC) with 

an appropriate detector, infrared (IR), fourier transform 

infrared (FTIR), and nuclear magnetic resonance (NMR). 

Acceptable methods include EPA Method 18 in appendix A–1 of 

40 CFR part 60; EPA Method 320 in appendix A of 40 CFR part 

63; the Protocol for Measuring Destruction or Removal 

Efficiency (DRE) of Fluorinated Greenhouse Gas Abatement 

Equipment in Electronics Manufacturing, Version 1, EPA–430–

R–10–003, (March 2010) (incorporated by reference, see 

§98.7); ASTM D6348–03 Standard Test Method for 

Determination of Gaseous Compounds by Extractive Direct 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Interface Fourier Transform Infrared (FTIR) Spectroscopy 

(incorporated by reference, see §98.7); or other analytical 

methods validated using EPA Method 301 in appendix A of 40 

CFR part 63 or some other scientifically sound validation 

protocol. The validation protocol may include analytical 

technology manufacturer specifications or recommendations.

(2) Documentation in GHG Monitoring Plan. Describe the 

analytical method(s) used under paragraph (n)(1) of this 

section in the site GHG Monitoring Plan as required under 

§98.3(g)(5). At a minimum, include in the description of

the method a description of the analytical measurement 

equipment and procedures, quantitative estimates of the 

method's accuracy and precision for the analytes of 

interest at the concentrations of interest, as well as a 

description of how these accuracies and precisions were 

estimated, including the validation protocol used.

(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 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 419 of 520

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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.

(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-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.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(o) All analytical equipment used to determine the 

concentration of fluorinated GHGs, including but not 

limited to gas chromatographs and associated detectors, IR, 

FTIR and NMR devices, shall be calibrated at a frequency 

needed to support the type of analysis specified in the 

site GHG Monitoring Plan as required under §§98.414(n) and 

98.3(g)(5) of this part. Quality assurance samples at the 

concentrations of concern shall be used for the 

calibration. Such quality assurance samples shall consist 

of or be prepared from certified standards of the analytes 

of concern where available; if not available, calibration 

shall be performed by a method specified in the GHG 

Monitoring Plan.

(p) Isolated intermediates that are produced and 

transformed at the same facility are exempt from the 

monitoring requirements of this section.

(q) Low-concentration constituents are exempt from the 

monitoring and QA/QC requirements of this section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 421 of 520

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[74 FR 56374, Oct. 30, 2009, as amended at 75 FR 79167, 

Dec. 17, 2010]

§ 98.415 Procedures for estimating missing data.

(a) A complete record of all measured parameters used in 

the GHG emissions calculations is required. Therefore, 

whenever a quality-assured value of a required parameter is 

unavailable (e.g., if a meter malfunctions), a substitute 

data value for the missing parameter shall be used in the 

calculations, according to paragraph (b) of this section.

(b) For each missing value of the mass produced, fed into 

the production process (for used material being reclaimed), 

fed into the transformation process, fed into destruction 

devices, sent to another facility for transformation, or 

sent to another facility for destruction, the substitute 

value of that parameter shall be a secondary mass 

measurement where such a measurement is available. For 

example, if the mass produced is usually measured with a 

flowmeter at the inlet to the day tank and that flowmeter 

fails to meet an accuracy or precision test, malfunctions, 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 422 of 520

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or is rendered inoperable, then the mass produced may be 

estimated by calculating the change in volume in the day 

tank and multiplying it by the density of the product. 

Where a secondary mass measurement is not available, the 

substitute value of the parameter shall be an estimate 

based on a related parameter. For example, if a flowmeter 

measuring the mass fed into a destruction device is 

rendered inoperable, then the mass fed into the destruction 

device may be estimated using the production rate and the 

previously observed relationship between the production 

rate and the mass flow rate into the destruction device.

§ 98.416 Data reporting requirements.

In addition to the information required by §98.3(c), each 

annual report must contain the following information:

(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
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 423 of 520

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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.

(4) [Reserved]

(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 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 424 of 520

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§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.

(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.

(8)[Reserved]

(9) [Reserved]

(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 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 425 of 520

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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.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 426 of 520

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(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.

(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.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(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.

(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 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 428 of 520

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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.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(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) of each fluorinated GHG that were sold or transferred 

to each facility for destruction.

(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:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 430 of 520

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(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.

(e) By March 31, 2011, or within 60 days of commencing 

fluorinated GHG production, whichever is later, a 

fluorinated GHG production facility shall submit a one-time 

report describing the following information:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(1) The method(s) by which the producer in practice 

measures the mass of fluorinated GHGs produced, including 

the instrumentation used (Coriolis flowmeter, other 

flowmeter, weigh scale, etc.) and its accuracy and 

precision.

(2) The method(s) by which the producer in practice 

estimates the mass of fluorinated GHGs fed into the 

transformation process, including the instrumentation used 

(Coriolis flowmeter, other flowmeter, weigh scale, etc.) 

and its accuracy and precision.

(3) The method(s) by which the producer in practice 

estimates the fraction of fluorinated GHGs fed into the 

transformation process that is actually transformed, and 

the estimated precision and accuracy of this estimate.

(4) The method(s) by which the producer in practice 

estimates the masses of fluorinated GHGs fed into the 

destruction device, including the method(s) used to 

estimate the concentration of the fluorinated GHGs in the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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destroyed material, and the estimated precision and 

accuracy of this estimate.

(5) The estimated percent efficiency of each production 

process for the fluorinated GHG produced.

(f) By March 31, 2011, all fluorinated GHG production 

facilities shall submit a one-time report that includes the 

concentration of each fluorinated GHG constituent in each 

fluorinated GHG product as measured under §98.414(n). If 

the facility commences production of a fluorinated GHG 

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 

GHG constituents of a fluorinated GHG product have changed, 

then the new or changed concentrations, as well as the date 

of the change, must be reflected in a revision to the 

report. The revised report must be submitted to EPA by the 

March 31st that immediately follows the measurement under 

§98.414(n).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(g) Isolated intermediates that are produced and 

transformed at the same facility are exempt from the 

reporting requirements of this section.

(h) Low-concentration constituents are exempt from the 

reporting requirements of this section.

[74 FR 56374, Oct. 30, 2009, as amended at 75 FR 79168, 

Dec. 17, 2010]

§ 98.417 Records that must be retained.

(a) In addition to the data required by §98.3(g), the 

fluorinated GHG production facility shall retain the 

following records:

(1) Dated records of the data used to estimate the data 

reported under §98.416.

(2) Records documenting the initial and periodic 

calibration of the analytical equipment (including but not 

limited to GC, IR, FTIR, or NMR), weigh scales, flowmeters, 

and volumetric and density measures used to measure the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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quantities reported under this subpart, including the 

manufacturer directions or industry standards used for 

calibration pursuant to §98.414(m) and (o).

(3) Dated records of the total mass in metric tons of each 

reactant fed into the F–GHG or nitrous oxide production 

process, by process.

(4) Dated records of the total mass in metric tons of the 

reactants, by-products, and other wastes permanently 

removed from the F–GHG or nitrous oxide production process, 

by process.

(b) In addition to the data required by paragraph (a) of 

this section, any fluorinated GHG production facility that 

destroys fluorinated GHGs shall keep records of test 

reports and other information documenting the facility's 

one-time destruction efficiency report in §98.416(b).

(c) In addition to the data required by §98.3(g), the bulk 

importer shall retain the following records substantiating 

each of the imports that they report:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(1) A copy of the bill of lading for the import.

(2) The invoice for the import.

(3) The U.S. Customs entry form.

(d) In addition to the data required by §98.3(g), the bulk 

exporter shall retain the following records substantiating 

each of the exports that they report:

(1) A copy of the bill of lading for the export and

(2) The invoice for the export.

(e) Every person who imports a container with a heel that 

is not reported under §98.416(c) shall keep records of the 

amount brought into the United States that document that 

the residual amount in each shipment is less than 10 

percent of the volume of the container and will:

(1) Remain in the container and be included in a future 

shipment.

(2) Be recovered and transformed.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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(3) Be recovered and destroyed.

(4) Be recovered and included in a future shipment.

(f) Isolated intermediates that are produced and 

transformed at the same facility are exempt from the 

recordkeeping requirements of this section.

(g) Low-concentration constituents are exempt from the 

recordkeeping requirements of this section.

[74 FR 56374, Oct. 30, 2009, as amended at 75 FR 79168, 

Dec. 17, 2010]

§ 98.418 Definitions.

Except as provided below, all of the terms used in this 

subpart have the same meaning given in the Clean Air Act 

and subpart A of this part. If a conflict exists between a 

definition provided in this subpart and a definition 

provided in subpart A, the definition in this subpart shall 

take precedence for the reporting requirements in this 

subpart.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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Isolated intermediate means a product of a process that is 

stored before subsequent processing. An isolated 

intermediate is usually a product of chemical synthesis. 

Storage of an isolated intermediate marks the end of a 

process. Storage occurs at any time the intermediate is 

placed in equipment used solely for storage.

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. Low-concentration 

constituents do not include fluorinated GHGs that are 

deliberately combined with the product ( e.g., to affect 

the performance characteristics of the product).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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Subpart RR—Geologic Sequestration of Carbon Dioxide

§98.440 Definition of the source category.

(a) The geologic sequestration of carbon dioxide (CO2)

source category comprises any well or group of wells that 

inject a CO2 stream for long-term containment in subsurface 

geologic formations. 

(b) This source category includes all wells permitted 

as Class VI under the Underground Injection Control 

program. 

(c) This source category does not include a well or 

group of wells where a CO2 stream is being injected in 

subsurface geologic formations to enhance the recovery of 

oil or natural gas unless one of the following applies:

(1) The owner or operator injects the CO2 stream for 

long-term containment in subsurface geologic formations and 

has chosen to submit a proposed monitoring, reporting, and 

verification (MRV) plan to EPA and received an approved 

plan from EPA.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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(2) The well is permitted as Class VI under the 

Underground Injection Control program.

(d) Exemption for research and development projects. 

Research and development projects shall receive an 

exemption from reporting under this subpart for the 

duration of the research and development activity.

(1) Process for obtaining an exemption. If you are a 

research and development project, you must submit the 

information in paragraph (d)(2) of this section to EPA by 

the time you would be otherwise required to submit an MRV 

plan under §98.448. EPA will use this information to verify 

that the project is a research and development project.

(2) Content of submission. A submission in support of 

an exemption as a research and development project must 

contain the following information:

(i) The planned duration of CO2 injection for the 

project.

(ii) The planned annual CO2 injection volumes during 

this time period.

(iii) The research purposes of the project.

(iv) The source and type of funding for the project.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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(v) The class and duration of Underground Injection 

Control permit or, for an offshore facility not subject to 

the Safe Drinking Water Act, a description of the legal 

instrument authorizing geologic sequestration.

(3) Determination by the Administrator. 

(i) The Administrator shall determine if a project 

meets the definition of research and development project 

within 60 days of receipt of the submission of a request 

for exemption. In making this determination, the 

Administrator shall take into account any information you 

submit demonstrating that the planned duration of CO2

injection for the project and the planned annual CO2

injection volumes during the duration of the project are 

consistent with the purpose of the research and development 

project.

(ii) Any appeal of the Administrator’s determination 

is subject to the provisions of part 78 of this chapter. 

(iii) A project that the Administrator determines is 

not eligible for an exemption as a research and development 

project must submit a proposed MRV plan to EPA within 180 

days of the Administrator’s determination. You may request 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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one extension of up to an additional 180 days in which to 

submit the proposed MRV plan.

§98.441 Reporting threshold.

(a) You must report under this subpart if any well or 

group of wells within your facility injects any amount of 

CO2 for long-term containment in subsurface geologic 

formations. There is no threshold.

(b) Request for discontinuation of reporting. The 

requirements of §98.2(i) do not apply to this subpart. 

Once a well or group of wells is subject to the 

requirements of this subpart, the owner or operator must 

continue for each year thereafter to comply with all 

requirements of this subpart, including the requirement to 

submit annual reports, until the Administrator has issued a 

final decision on an owner or operator’s request to 

discontinue reporting.

(1) Timing of request. The owner or operator of a 

facility may submit a request to discontinue reporting any 

time after the well or group of wells is plugged and 

abandoned in accordance with applicable requirements. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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(2) Content of request. A request for 

discontinuation of reporting must contain either paragraph

(b)(2)(i) or (b)(2)(ii) of this section.

(i) For wells permitted as Class VI under the 

Underground Injection Control program, a copy of the 

applicable Underground Injection Control program Director’s 

authorization of site closure.

(ii) For all other wells, and as an alternative for 

wells permitted as Class VI under the Underground Injection 

Control program, a demonstration that current monitoring 

and model(s) show that the injected CO2 stream is not 

expected to migrate in the future in a manner likely to 

result in surface leakage. 

(3) Notification. The Administrator will issue a 

final decision on the request to discontinue reporting 

within a reasonable time. Any appeal of the 

Administrator’s final decision is subject to the provisions 

of part 78 of this chapter.

§98.442 GHGs to report.

You must report:

(a) Mass of CO2 received.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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(b) Mass of CO2 injected into the subsurface. 

(c) Mass of CO2 produced.

(d) Mass of CO2 emitted by surface leakage.

(e) Mass of CO2 emissions from equipment leaks and

vented emissions of CO2from surface equipment located 

between the injection flow meter and the injection 

wellhead.

(f) Mass of CO2 emissions from equipment leaks and 

vented emissions of CO2 from surface equipment located 

between the production flow meter and the production 

wellhead.

(g) Mass of CO2 sequestered in subsurface geologic 

formations.

(h) Cumulative mass of CO2 reported as sequestered in 

subsurface geologic formations in all years since the 

facility became subject to reporting requirements under 

this subpart.

§98.443 Calculating CO2 geologic sequestration.

You must calculate the mass of CO2 received using CO2

received equations (Equations RR-1 to RR-3 of this 

section), unless you follow the procedures in 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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§98.444(a)(4). You must calculate CO2 sequestered using 

injection equations (Equations RR-4 to RR-6 of this 

section), production/recycling equations (Equations RR-7 to 

RR-9 of this section), surface leakage equations (Equation 

RR-10 of this section), and sequestration equations 

(Equations RR-11 and RR-12 of this section). For your 

first year of reporting, you must calculate CO2 sequestered 

starting from the date set forth in your approved MRV plan. 

(a) You must calculate and report the annual mass of

CO2 received by pipeline using the procedures in paragraphs 

(a)(1) or (a)(2) of this section and the procedures in 

paragraph (a)(3) of this section, if applicable.

(1) For a mass flow meter, you must calculate the 

total annual mass of CO2 in a CO2 stream received in metric 

tons by multiplying the mass flow by the CO2 concentration 

in the flow, according to Equation RR-1 of this section. 

You must collect these data quarterly. Mass flow and 

concentration data measurements must be made in accordance 

with §98.444.

CO2T,r = p CO p r

r

p

Qr p S C 2, ,( ,) *

4

1

 , 



(Eq. RR-1)
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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Where: 

CO2T,r = Net annual mass of CO2 received through flow 

meter r (metric tons). 

Qr,p = Quarterly mass flow through a receiving flow 

meter r in quarter p (metric tons). 

Sr,p = Quarterly mass flow through a receiving flow 

meter r that is redelivered to another facility 

without being injected into your well in 

quarter p (metric tons). 

CCO2,p,r = Quarterly CO2 concentration measurement in flow

for flow meter r in quarter p (wt. percent CO2, 

expressed as a decimal fraction).

p = Quarter of the year.

r = Receiving flow meter.

(2) For a volumetric flow meter, you must calculate 

the total annual mass of CO2 in a CO2 stream received in 

metric tons by multiplying the volumetric flow at standard 

conditions by the CO2 concentration in the flow and the 

density of CO2 at standard conditions, according to Equation 

RR-2 of this section. You must collect these data 

quarterly. Volumetric flow and concentration data 

measurements must be made in accordance with §98.444.

CO2T,r = CO p r

p

Qr p Sr p D C 2, ,( ) * *

4

1

 , ,



 (Eq. RR-2)

Where: 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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CO2T,r = Net annual mass of CO2 received through flow 

meter r (metric tons). 

Qr,p = Quarterly volumetric flow through a receiving 

flow meter r in quarter p at standard 

conditions (standard cubic meters).

Sr,p = Quarterly volumetric flow through a receiving 

flow meter r that is redelivered to another 

facility without being injected into your well 

in quarter p (standard cubic meters).

D = Density of CO2 at standard conditions (metric 

tons per standard cubic meter): 0.0018682.

CCO2,p,r = Quarterly CO2 concentration measurement in flow 

for flow meter r in quarter p (vol. percent 

CO2, expressed as a decimal fraction).

p = Quarter of the year.

r = Receiving flow meter.

(3) If you receive CO2 through more than one flow 

meter, you must sum the mass of all CO2 received in 

accordance with the procedure specified in Equation RR-3 of 

this section. 

CO2 = 

R

r 1

CO2T,r (Eq. RR-3)

Where: 

CO2 = Total net annual mass of CO2 received (metric 

tons). 

CO2T,r = Net annual mass of CO2 received (metric tons) 

as calculated in Equation RR-1 or RR-2 for

flow meter r. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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r = Receiving flow meter.

(b) You must calculate and report the annual mass of

CO2 received in containers using the procedures in 

paragraphs (b)(1) or (b)(2) of this section. 

(1) If you are measuring the mass of contents in a 

container under the provisions of §98.444(a)(2)(i), you 

must calculate the CO2 received for injection in containers 

using Equation RR-1 of this section.

Where: 

CO2T,r = Net annual mass of CO2 received in containers r 

(metric tons). 

CCO2,p,r = Quarterly CO2 concentration measurement of 

contents in containers r in quarter p (wt. 

percent CO2, expressed as a decimal fraction).

Qr,p = Quarterly mass of contents in containers r in 

quarter p (metric tons). 

Sr,p = Quarterly mass of contents in containers r 

redelivered to another facility without being 

injected into your well in quarter p (metric 

tons). 

p = Quarter of the year.

r = Containers.

(2) If you are measuring the volume of contents in a 

container under the provisions of §98.444(a)(2)(ii), you 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Page 448 of 520

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must calculate the CO2 received for injection in containers 

using Equation RR-2 of this section.

Where: 

CO2T,r = Net annual mass of CO2 received in containers r 

(metric tons).

CCO2,p,r = Quarterly CO2 concentration measurement of 

contents in containers r in quarter p (vol. 

percent CO2, expressed as a decimal fraction).

Qr,p = Quarterly volume of contents in containers r in 

quarter p (standard cubic meters).

Sr,p = Quarterly mass of contents in containers r 

redelivered to another facility without being 

injected into your well in quarter p (metric 

tons). 

D = Density of the CO2 received in containers at 

standard conditions (metric tons per standard 

cubic meter):0.0018682. 

p = Quarter of the year.

r = Containers.

(c) You must report the annual mass of CO2 injected in 

accordance with the procedures specified in paragraphs 

(c)(1) through (c)(3) of this section.

(1) If you use a mass flow meter to measure the flow 

of an injected CO2 stream, you must calculate annually the 

total mass of CO2 (in metric tons) in the CO2 stream 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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injected each year in metric tons by multiplying the mass 

flow by the CO2 concentration in the flow, according to 

Equation RR-4 of this section. Mass flow and concentration 

data measurements must be made in accordance with §98.444.

CO2,u = CO p u

p

Qp u C 2, ,*

4

1

 ,



(Eq. RR-4)

Where: 

CO2,u = Annual CO2 mass injected (metric tons) as 

measured by flow meter u.

Qp,u = Quarterly mass flow rate measurement for flow 

meter u in quarter p (metric tons per quarter).

CCO2,p,u = Quarterly CO2 concentration measurement in flow 

for flow meter u in quarter p (wt. percent CO2, 

expressed as a decimal fraction).

p = Quarter of the year.

u = Flow meter.

(2) If you use a volumetric flow meter to measure the 

flow of an injected CO2 stream, you must calculate annually 

the total mass of CO2 (in metric tons) in the CO2 stream 

injected each year in metric tons by multiplying the 

volumetric flow at standard conditions by the CO2

concentration in the flow and the density of CO2 at standard

conditions, according to Equation RR-5 of this section. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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Volumetric flow and concentration data measurements must be 

made in accordance with §98.444.

CO2,u = CO p u

p

Qp u D C 2, ,* *

4

1

 ,



(Eq. RR-5)

Where: 

CO2,u = Annual CO2 mass injected (metric tons) as 

measured by flow meter u.

Qp,u = Quarterly volumetric flow rate measurement for 

flow meter u in quarter p at standard 

conditions (standard cubic meters per quarter).

D = Density of CO2 at standard conditions (metric 

tons per standard cubic meter): 0.0018682.

CCO2,p,u = CO2 concentration measurement in flow for flow 

meter u in quarter p (vol. percent CO2, 

expressed as a decimal fraction).

p = Quarter of the year.

u = Flow meter.

(3) To aggregate injection data for all wells covered 

under this subpart, you must sum the mass of all CO2

injected through all injection wells in accordance with the 

procedure specified in Equation RR-6 of this section. 

CO2I = 

U

u 1

CO2, u (Eq. RR-6)

Where: 

CO2I = Total annual CO2 mass injected (metric tons) 

through all injection wells. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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CO2,u = Annual CO2 mass injected (metric tons) as 

measured by flow meter u. 

u = Flow meter.

(d) You must calculate the annual mass of CO2 produced 

from oil or gas production wells or from other fluid wells 

for each separator that sends a stream of gas into a 

recycle or end use system in accordance with the procedures 

specified in paragraphs (d)(1) through (d)(3) of this 

section. You must account for any CO2 that is produced and 

not processed through a separator. You must account only 

for wells that produce the CO2 that was injected into the 

well or wells covered by this source category.

(1) For each gas-liquid separator for which flow is 

measured using a mass flow meter, you must calculate 

annually the total mass of CO2 produced from an oil or other 

fluid stream in metric tons that is separated from the 

fluid by multiplying the mass gas flow by the CO2

concentration in the gas flow, according to Equation RR-7

of this section. You must collect these data quarterly. 

Mass flow and concentration data measurements must be made 

in accordance with §98.444.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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CO2,w = CO p w

p

Qp w C 2, ,*

4

1

 ,



(Eq. RR-7)

Where: 

CO2,w = Annual CO2 mass produced (metric tons) through 

separator w. 

Qp,w = Quarterly gas mass flow rate measurement for 

separator w in quarter p (metric tons). 

CCO2,p,w = Quarterly CO2 concentration measurement in flow 

for separator w in quarter p (wt. percent CO2, 

expressed as a decimal fraction).

p = Quarter of the year.

w = Separator.

(2) For each gas-liquid separator for which flow is 

measured using a volumetric flow meter, you must calculate 

annually the total mass of CO2 produced from an oil or other 

fluid stream in metric tons that is separated from the 

fluid by multiplying the volumetric gas flow at standard 

conditions by the CO2 concentration in the gas flow and the 

density of CO2 at standard conditions, according to Equation 

RR-8 of this section. You must collect these data 

quarterly. Volumetric flow and concentration data 

measurements must be made in accordance with §98.444.

CO2,w = CO p w

p

Qp w D C 2, ,* *

4

1

 ,



(Eq. RR-8)
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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Where: 

CO2,w = Annual CO2 mass produced (metric tons) through 

separator w. 

Qp,w = Volumetric gas flow rate measurement for 

separator w in quarter p at standard conditions

(standard cubic meters).

D = Density of CO2 at standard conditions (metric 

tons per standard cubic meter): 0.0018682.

CCO2,p,w = CO2 concentration measurement in flow for 

separator w in quarter p (vol. percent CO2, 

expressed as a decimal fraction).

p = Quarter of the year.

w = Separator.

(3) To aggregate production data, you must sum the 

mass of all of the CO2 separated at each gas-liquid 

separator in accordance with the procedure specified in 

Equation RR-9 of this section. You must assume that the 

total CO2 measured at the separator(s) represents a 

percentage of the total CO2 produced. In order to account 

for the percentage of CO2 produced that is estimated to 

remain with the produced oil or other fluid, you must 

multiply the quarterly mass of CO2 measured at the 

separator(s) by a percentage estimated using a methodology 

in your approved MRV plan. If fluids containing CO2 from 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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injection wells covered under this source category are 

produced and not processed through a gas-liquid separator, 

the concentration of CO2 in the produced fluids must be 

measured at a flow meter located prior to reinjection or 

reuse using methods in §98.444(f)(1). The considerations 

you intend to use to calculate CO2 from produced fluids for 

the mass balance equation must be described in your 

approved MRV plan in accordance with §98.448(d)(5).

CO2P = (1+X) * 

W

w 1

CO2, w (Eq. RR-9)

Where: 

CO2P = Total annual CO2 mass produced (metric tons) 

through all separators in the reporting year. 

CO2,w = Annual CO2 mass produced (metric tons) through 

separator w in the reporting year. 

X = Entrained CO2 in produced oil or other fluid

divided by the CO2 separated through all 

separators in the reporting year (weight

percent CO2, expressed as a decimal fraction).

w = Separator.

(e) You must report the annual mass of CO2 that is 

emitted by surface leakage in accordance with your approved 

MRV plan. You must calculate the total annual mass of CO2
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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emitted from all leakage pathways in accordance with the 

procedure specified in Equation RR-10 of this section.

CO2E = 

X

x 1

CO2, x (Eq. RR-10)

Where: 

CO2E = Total annual CO2 mass emitted by surface 

leakage (metric tons) in the reporting year. 

CO2,x = Annual CO2 mass emitted (metric tons) at 

leakage pathway x in the reporting year. 

x = Leakage pathway. 

(f) You must report the annual mass of CO2 that is 

sequestered in subsurface geologic formations in the 

reporting year in accordance with the procedures specified 

in paragraphs (f)(1) and (f)(2) of this section. 

(1) If you are actively producing oil or natural gas 

or if you are producing any other fluids, you must 

calculate the annual mass of CO2 that is sequestered in the 

underground subsurface formation in the reporting year in 

accordance with the procedure specified in Equation RR-11

of this section.

CO2 = CO2I - CO2P – CO2E – CO2FI – CO2FP (Eq. RR-11)

Where: 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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CO2 = Total annual CO2 mass sequestered in subsurface 

geologic formations (metric tons) at the 

facility in the reporting year. 

CO2I = Total annual CO2 mass injected (metric tons) in 

the well or group of wells covered by this 

source category in the reporting year.

CO2P = Total annual CO2 mass produced (metric tons) in 

the reporting year.

CO2E = Total annual CO2 mass emitted (metric tons) by 

surface leakage in the reporting year.

CO2FI = Total annual CO2 mass emitted (metric tons) 

from equipment leaks and vented emissions of 

CO2 from equipment located on the surface 

between the flow meter used to measure 

injection quantity and the injection wellhead, 

for which a calculation procedure is provided 

in subpart W of this part.

CO2FP = Total annual CO2 mass emitted (metric tons) 

from equipment leaks and vented emissions of 

CO2 from equipment located on the surface 

between the production wellhead and the flow 

meter used to measure production quantity, for 

which a calculation procedure is provided in 

subpart W of this part.

(2) If you are not actively producing oil or natural 

gas or any other fluids, you must calculate the annual mass 

of CO2 that is sequestered in subsurface geologic formations

in the reporting year in accordance with the procedures 

specified in Equation RR-12 of this section.

CO2 = CO2I – CO2E – CO2FI (Eq. RR-12)
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Where: 

CO2 = Total annual CO2 mass sequestered in subsurface 

geologic formations (metric tons) at the 

facility in the reporting year. 

CO2I = Total annual CO2 mass injected (metric tons) in 

the well or group of wells covered by this 

source category in the reporting year.

CO2E = Total annual CO2 mass emitted (metric tons) by 

surface leakage in the reporting year.

CO2FI = Total annual CO2 mass emitted (metric tons) 

from equipment leaks and vented emissions of 

CO2 from equipment located on the surface 

between the flow meter used to measure 

injection quantity and the injection wellhead.

§98.444 Monitoring and QA/QC requirements.

(a) CO2 received.

(1) Except as provided in paragraph (a)(4) of this 

section, you must determine the quarterly flow rate of CO2

received by pipeline by following the most appropriate of 

the following procedures:

(i) You may measure flow rate at the receiving 

custody transfer meter prior to any subsequent processing 

operations at the facility and collect the flow rate 

quarterly. 

(ii) If you took ownership of the CO2 in a commercial 

transaction, you may use the quarterly flow rate data from 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 458 of 520

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the sales contract if it is a one-time transaction or from 

invoices or manifests if it is an ongoing commercial 

transaction with discrete shipments.

(iii) If you inject CO2 received from a production 

process unit that is part of your facility, you may use the 

quarterly CO2 flow rate that was measured at the equivalent 

of a custody transfer meter following procedures provided 

in subpart PP of this part. To be the equivalent of a 

custody transfer meter, a meter must measure the flow of CO2

being transported to an injection well to the same degree 

of accuracy as a meter used for commercial transactions.

(2) Except as provided in paragraph (a)(4) of this 

section, you must determine the quarterly mass or volume of 

contents in all containers if you receive CO2 in containers

by following the most appropriate of the following 

procedures:

(i) You may measure the mass of contents of

containers summed quarterly using weigh bills, scales, or 

load cells. 

(ii) You may determine the volume of the contents of

containers summed quarterly.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(iii) If you took ownership of the CO2 in a commercial 

transaction, you may use the quarterly mass or volume of 

contents from the sales contract if it is a one-time 

transaction or from invoices or manifests if it is an 

ongoing commercial transaction with discrete shipments.

(3) Except as provided in paragraph (a)(4) of this 

section, you must determine a quarterly concentration of 

the CO2 received that is representative of all CO2 received 

in that quarter by following the most appropriate of the 

following procedures:

(i) You may sample the CO2 stream at least once per 

quarter at the point of receipt and measure its CO2

concentration.

(ii) If you took ownership of the CO2 in a commercial 

transaction for which the sales contract was contingent on 

CO2 concentration, and if the supplier of the CO2 sampled 

the CO2 stream in a quarter and measured its concentration

per the sales contract terms, you may use the CO2

concentration data from the sales contract for that 

quarter.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(iii) If you inject CO2 from a production process unit 

that is part of your facility, you may report the quarterly 

CO2 concentration of the CO2 stream supplied that was 

measured following the procedures provided in subpart PP of 

this part. 

(4) If the CO2 you receive is wholly injected and is 

not mixed with any other supply of CO2, you may report the 

annual mass of CO2 injected that you determined following 

the requirements under paragraph (b) of this section as the 

total annual mass of CO2 received instead of using Equation 

RR-1 or RR-2 of this subpart to calculate CO2 received.

(5) You must assume that the CO2 you receive meets the 

definition of a CO2 stream unless you can trace it through 

written records to a source other than a CO2 stream. 

(b) CO2 injected.

(1) You must select a point or points of measurement 

at which the CO2 stream(s) is representative of the CO2

stream(s) being injected. You may use as the point or 

points of measurement the location(s) of the flow meter(s)

used to comply with the flow monitoring and reporting 

provisions in your Underground Injection Control permit.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(2) You must measure flow rate of CO2 injected with a 

flow meter and collect the flow rate quarterly.

(3) You must sample the injected CO2 stream at least 

once per quarter immediately upstream or downstream of the 

flow meter used to measure flow rate of that CO2 stream and 

measure the CO2 concentration of the sample.

(c) CO2 produced.

(1) The point of measurement for the quantity of CO2

produced from oil or other fluid production wells is a flow 

meter directly downstream of each separator that sends a 

stream of gas into a recycle or end use system. 

(2) You must sample the produced gas stream at least 

once per quarter immediately upstream or downstream of the 

flow meter used to measure flow rate of that gas stream and 

measure the CO2 concentration of the sample.

(3) You must measure flow rate of gas produced with a 

flow meter and collect the flow rate quarterly. 

(d) CO2 emissions from equipment leaks and vented 

emissions of CO2. If you have equipment located on the 

surface between the flow meter used to measure injection 

quantity and the injection wellhead or between the flow 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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meter used to measure production quantity and the 

production wellhead, you must follow the monitoring and 

QA/QC requirements specified in subpart W of this part for 

the equipment.

(e) Measurement devices.

(1) All flow meters must be operated continuously 

except as necessary for maintenance and calibration.

(2) You must calibrate all flow meters used to 

measure quantities reported in §98.446 according to the 

calibration and accuracy requirements in §98.3(i).

(3) You must operate all measurement devices 

according to one of the following. You may use an 

appropriate standard method published by a consensus-based 

standards organization if such a method exists or an 

industry standard practice. Consensus-based standards 

organizations include, but are not limited to, the 

following: ASTM International, the American National 

Standards Institute (ANSI), the American Gas Association 

(AGA), the American Society of Mechanical Engineers (ASME), 

the American Petroleum Institute (API), and the North 

American Energy Standards Board (NAESB). 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(4) You must ensure that any flow meter calibrations 

performed are National Institute of Standards and 

Technology (NIST) traceable.

(f) General. 

(1) If you measure the concentration of any CO2

quantity for reporting, you must measure according to one 

of the following. You may use an appropriate standard 

method published by a consensus-based standards 

organization if such a method exists or an industry 

standard practice.

(2) You must convert all measured volumes of CO2 to 

the following standard industry temperature and pressure 

conditions for use in Equations RR-2, RR-5 and RR-8 of this 

subpart: standard cubic meters at a temperature of 60 

degrees Fahrenheit and at an absolute pressure of 1 

atmosphere.

(3) For 2011, you may follow the provisions of 

§98.3(d)(1) through (2) for best available monitoring 

methods only for parameters required by paragraphs (a) and 

(b) of §98.443 rather than follow the monitoring 

requirements of paragraph (a) of this section. For 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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purposes of this subpart, any reference to the year 2010 in 

§98.3(d)(1) through (2) shall mean 2011.

§98.445 Procedures for estimating missing data.

A complete record of all measured parameters used in 

the GHG quantities calculations is required. Whenever the 

monitoring procedures cannot be followed, you must use the 

following missing data procedures:

(a) A quarterly flow rate of CO2 received that is 

missing must be estimated as follows:

(1) Another calculation methodology listed in 

§98.444(a)(1) must be used if possible. 

(2) If another method listed in §98.444(a)(1) cannot 

be used, a quarterly flow rate value that is missing must 

be estimated using a representative flow rate value from 

the nearest previous time period.

(b) A quarterly mass or volume of contents in 

containers received that is missing must be estimated as 

follows:

(1) Another calculation methodology listed in 

§98.444(a)(2) must be used if possible. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(2) If another method listed in §98.444(a)(2) cannot 

be used, a quarterly mass or volume value that is missing 

must be estimated using a representative mass or volume

value from the nearest previous time period. 

(c) A quarterly CO2 concentration of a CO2 stream 

received that is missing must be estimated as follows:

(1) Another calculation methodology listed in 

§98.444(a)(3) must be used if possible. 

(2) If another method listed in §98.444(a)(3) cannot 

be used, a quarterly concentration value that is missing 

must be estimated using a representative concentration

value from the nearest previous time period.

(d) A quarterly quantity of CO2 injected that is 

missing must be estimated using a representative quantity

of CO2 injected from the nearest previous period of time at 

a similar injection pressure.

(e) For any values associated with CO2 emissions from 

equipment leaks and vented emissions of CO2 from surface 

equipment at the facility that are reported in this 

subpart, missing data estimation procedures should be 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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followed in accordance with those specified in subpart W of 

this part.

(f) The quarterly quantity of CO2 produced from 

subsurface geologic formations that is missing must be 

estimated using a representative quantity of CO2 produced

from the nearest previous period of time.

(g) You must estimate the mass of CO2 emitted by

surface leakage that is missing as required by your 

approved MRV plan.

(h) You must estimate other missing data as required 

by your approved MRV plan.

§98.446 Data reporting requirements.

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

report the information listed in this section.

(a) If you receive CO2 by pipeline, report the 

following for each receiving flow meter:

(1) The total net mass of CO2 received (metric tons) 

annually. 

(2) If a volumetric flow meter is used to receive CO2

report the following unless you reported yes to paragraph 

(a)(4) of this section:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(i) The volumetric flow through a receiving flow 

meter at standard conditions (in standard cubic meters) in 

each quarter.

(ii) The volumetric flow through a receiving flow 

meter that is redelivered to another facility without being 

injected into your well (in standard cubic meters) in each 

quarter.

(iii) The CO2 concentration in the flow (volume 

percent CO2 expressed as a decimal fraction) in each 

quarter. 

(3) If a mass flow meter is used to receive CO2 report 

the following unless you reported yes to paragraph (a)(4) 

of this section:

(i) The mass flow through a receiving flow meter (in 

metric tons) in each quarter.

(ii) The mass flow through a receiving flow meter 

that is redelivered to another facility without being 

injected into your well (in metric tons) in each quarter.

(iii) The CO2 concentration in the flow (weight

percent CO2 expressed as a decimal fraction) in each 

quarter. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(4) If the CO2 received is wholly injected and not 

mixed with any other supply of CO2, report whether you 

followed the procedures in §98.444(a)(4).

(5) The standard or method used to calculate each 

value in paragraphs (a)(2) through (a)(3) of this section.

(6) The number of times in the reporting year for 

which substitute data procedures were used to calculate 

values reported in paragraphs (a)(2) through (a)(3) of this 

section.

(7) Whether the flow meter is mass or volumetric.

(8) A numerical identifier for the flow meter.

(b) If you receive CO2 in containers, report:

(1) The mass (in metric tons) or volume at standard 

conditions (in standard cubic meters) of contents in 

containers received in each quarter.

(2) The concentration of CO2 of contents in containers

(volume or wt. percent CO2 expressed as a decimal fraction) 

in each quarter.

(3) The mass (in metric tons) or volume (in standard 

cubic meters) of contents in containers that is redelivered 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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to another facility without being injected into your well 

in each quarter.

(4) The net mass of CO2 received (in metric tons) 

annually. 

(5) The standard or method used to calculate each 

value in paragraphs (b)(1) and (b)(2) of this section.

(6) The number of times in the reporting year for 

which substitute data procedures were used to calculate 

values reported in paragraphs (b)(1) and (b)(2) of this 

section.

(c) If you use more than one receiving flow meter, 

report the total net mass of CO2 received (metric tons) 

through all flow meters annually.

(d) The source of the CO2 received according to the 

following categories:

(1) CO2 production wells.

(2) Electric generating unit.

(3) Ethanol plant.

(4) Pulp and paper mill.

(5) Natural gas processing.

(6) Gasification operations.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(7) Other anthropogenic source.

(8) Discontinued enhanced oil and gas recovery 

project.

(9) Unknown. 

(e) Report the date that you began collecting data 

for calculating total amount sequestered according to 

§98.448(a)(7) of this subpart. 

(f) Report the following. If the date specified in 

paragraph (e) of this section is during the reporting year 

for this annual report, report the following starting on 

the date specified in paragraph (e) of this section.

(1) For each injection flow meter (mass or 

volumetric), report:

(i) The mass of CO2 injected (metric tons) annually.

(ii) The CO2 concentration in flow (volume or weight 

percent CO2 expressed as a decimal fraction) in each 

quarter.

(iii) If a volumetric flow meter is used, the 

volumetric flow rate at standard conditions (in standard 

cubic meters) in each quarter. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(iv) If a mass flow meter is used, the mass flow rate 

(in metric tons) in each quarter.

(v) A numerical identifier for the flow meter.

(vi) Whether the flow meter is mass or volumetric. 

(vii) The standard used to calculate each value in 

paragraphs (f)(1)(ii) through (f)(1)(iv) of this section.

(viii) The number of times in the reporting year for 

which substitute data procedures were used to calculate 

values reported in paragraphs (f)(1)(ii) through (f)(1)(iv) 

of this section.

(ix) The location of the flow meter.

(2) The total CO2 injected (metric tons) in the 

reporting year as calculated in Equation RR-6 of this 

subpart.

(3) For CO2 emissions from equipment leaks and vented 

emissions of CO2, report the following:

(i) The mass of CO2 emitted (in metric tons) annually

from equipment leaks and vented emissions of CO2 from 

equipment located on the surface between the flow meter 

used to measure injection quantity and the injection 

wellhead.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(ii) The mass of CO2 emitted (in metric tons) annually

from equipment leaks and vented emissions of CO2 from 

equipment located on the surface between the production 

wellhead and the flow meter used to measure production 

quantity.

(4) For each separator flow meter (mass or 

volumetric), report: 

(i) CO2 mass produced (metric tons) annually. 

(ii) CO2 concentration in flow (volume or weight

percent CO2 expressed as a decimal fraction) in each 

quarter.

(iii) If a volumetric flow meter is used, volumetric

flow rate at standard conditions (standard cubic meters) in 

each quarter. 

(iv) If a mass flow meter, mass flow rate (metric 

tons) in each quarter. 

(v) A numerical identifier for the flow meter.

(vi) Whether the flow meter is mass or volumetric. 

(vii) The standard used to calculate each value in

paragraphs (f)(4)(ii) through (f)(4)(iv) of this section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(viii) The number of times in the reporting year for 

which substitute data procedures were used to calculate 

values reported in paragraphs (f)(4)(ii) through (f)(4)(iv) 

of this section.

(5) The entrained CO2 in produced oil or other fluid

divided by the CO2 separated through all separators in the 

reporting year (weight percent CO2 expressed as a decimal 

fraction) used as the value for X in Equation RR-9 of this 

subpart and as determined according to your EPA-approved 

MRV plan.

(6) Annual CO2 produced in the reporting year as 

calculated in Equation RR-9 of this subpart.

(7) For each leakage pathway through which CO2

emissions occurred, report:

(i) A numerical identifier for the leakage pathway.

(ii) The CO2 (metric tons) emitted through that 

pathway in the reporting year.

(8) Annual CO2 mass emitted (metric tons) by surface 

leakage in the reporting year as calculated by Equation RR10 of this subpart.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(9) Annual CO2 (metric tons) sequestered in subsurface 

geologic formations in the reporting year as calculated by 

Equation RR-11 or RR-12 of this subpart.

(10) Cumulative mass of CO2 (metric tons) reported as 

sequestered in subsurface geologic formations in all years 

since the well or group of wells became subject to 

reporting requirements under this subpart.

(11) Date that the most recent MRV plan was approved 

by EPA and the MRV plan approval number that was issued by 

EPA.

(12) An annual monitoring report that contains the 

following components:

(i) A narrative history of the monitoring efforts

conducted over the previous calendar year, including a 

listing of all monitoring equipment that was operated, its 

period of operation, and any relevant tests or surveys that 

were conducted. 

(ii) A description of any changes to the monitoring

program that you concluded were not material changes

warranting submission of a revised MRV plan under 

§98.448(d).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(iii) A narrative history of any monitoring anomalies 

that were detected in the previous calendar year and how 

they were investigated and resolved. 

(iv) A description of any surface leakages of CO2,

including a discussion of all methodologies and 

technologies involved in detecting and quantifying the 

surface leakages and any assumptions and uncertainties 

involved in calculating the amount of CO2 emitted. 

(13) If a well is permitted under the Underground 

Injection Control program, for each injection well, report:

(i) The well identification number used for the 

Underground Injection Control permit.

(ii) The Underground Injection Control permit class.

(14) If an offshore well is not subject to the Safe 

Drinking Water Act, for each injection well, report any 

well identification number and any identification number 

used for the legal instrument authorizing geologic 

sequestration.

§98.447 Records that must be retained.

(a) You must follow the record retention requirements 

specified by §98.3(g). In addition to the records required 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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by §98.3(g), you must retain the records specified in 

paragraphs (a)(1) through (7) of this section, as 

applicable. You must retain all required records for at 

least 3 years.

(1) Quarterly records of CO2 received, including mass

flow rate of contents of containers (mass or volumetric) at 

standard conditions and operating conditions, operating 

temperature and pressure, and concentration of these 

streams.

(2) Quarterly records of produced CO2, including mass 

flow or volumetric flow at standard conditions and 

operating conditions, operating temperature and pressure,

and concentration of these streams. 

(3) Quarterly records of injected CO2 including mass 

flow or volumetric flow at standard conditions and 

operating conditions, operating temperature and pressure,

and concentration of these streams.

(4) Annual records of information used to calculate 

the CO2 emitted by surface leakage from leakage pathways. 

(5) Annual records of information used to calculate 

the CO2 emitted from equipment leaks and vented emissions of 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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CO2 from equipment located on the surface between the flow 

meter used to measure injection quantity and the injection 

wellhead. 

(6) Annual records of information used to calculate 

the CO2 emitted from equipment leaks and vented emissions of 

CO2 from equipment located on the surface between the 

production wellhead and the flow meter used to measure 

production quantity.

(7) Any other records as specified for retention in 

your EPA-approved MRV plan.

(b) You must complete your monitoring plans, as 

described in §98.3(g)(5), by April 1 of the year you begin 

collecting data.

§98.448 Geologic sequestration monitoring, reporting, and 

verification (MRV) plan. 

(a) Contents of MRV plan. You must develop and 

submit to the Administrator a proposed MRV plan for 

monitoring, reporting, and verification of geologic 

sequestration at your facility. Your proposed MRV plan 

must contain the following components:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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(1) Delineation of the maximum monitoring area and 

the active monitoring areas. The first period for your 

active monitoring area will begin from the date determined 

in your MRV plan through the date at which the plan calls 

for the first expansion of the monitoring area. The length 

of each monitoring period can be any time interval chosen 

by you that is greater than 1 year.

(2) Identification of potential surface leakage 

pathways for CO2 in the maximum monitoring area and the 

likelihood, magnitude, and timing, of surface leakage of CO2

through these pathways.

(3) A strategy for detecting and quantifying any 

surface leakage of CO2.

(4) A strategy for establishing the expected 

baselines for monitoring CO2 surface leakage. 

(5) A summary of the considerations you intend to use

to calculate site-specific variables for the mass balance 

equation. This includes, but is not limited to, 

considerations for calculating CO2 emissions from equipment 

leaks and vented emissions of CO2 between the injection flow 

meter and injection well and/or the production flow meter 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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and production well, and considerations for calculating CO2

in produced fluids. 

(6) If a well is permitted under the Underground 

Injection Control program, for each injection well, report 

the well identification number used for the Underground 

Injection Control permit and the Underground Injection 

Control permit class. If the well is not yet permitted, 

and you have applied for an Underground Injection Control

permit, report the well identification numbers in the 

permit application. If an offshore well is not subject to 

the Safe Drinking Water Act, for each injection well, 

report any well identification number and any 

identification number used for the legal instrument

authorizing geologic sequestration. If you are submitting 

your Underground Injection Control permit application as 

part of your proposed MRV plan, you must notify EPA when 

the permit has been approved. If you are an offshore 

facility not subject to the Safe Drinking Water Act, and 

are submitting your application for the legal instrument 

authorizing geologic sequestration as part of your proposed 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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MRV plan, you must notify EPA when the legal instrument 

authorizing geologic sequestration has been approved.

(7) Proposed date to begin collecting data for 

calculating total amount sequestered according to equation 

RR-11 or RR-12 of this subpart. This date must be after 

expected baselines as required by paragraph (a)(4) of this 

section are established and the leakage detection and 

quantification strategy as required by paragraph (a)(3) of 

this section is implemented in the initial AMA.

(b) Timing. You must submit a proposed MRV plan to 

EPA according to the following schedule: 

(1) You must submit a proposed MRV plan to EPA by 

June 30, 2011 if you were issued a final Underground 

Injection Control permit authorizing the injection of CO2

into the subsurface on or before December 31, 2010. You 

will be allowed to request one extension of up to an 

additional 180 days in which to submit your proposed MRV 

plan.

(2) You must submit a proposed MRV plan to EPA within 

180 days of receiving a final Underground Injection Control

permit authorizing the injection of CO2 into the subsurface. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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If your facility is an offshore facility not subject to the 

Safe Drinking Water Act, you must submit a proposed MRV 

plan to EPA within 180 days of receiving authorization to 

begin geologic sequestration of CO2. You will be allowed to 

request one extension of the submittal date of up to an 

additional 180 days. 

(3) If you are injecting a CO2 stream in subsurface 

geologic formations to enhance the recovery of oil or 

natural gas and you are not permitted as Class VI under the 

Underground Injection Control program, you may opt to 

submit an MRV plan at any time.

(4) If EPA determines that your proposed MRV plan is 

incomplete, you must submit an updated MRV plan within 45 

days of EPA notification, unless otherwise specified by 

EPA.

(c) Final MRV plan. The Administrator will issue a 

final MRV plan within a reasonable period of time. The 

Administrator’s final MRV plan is subject to the provisions 

of part 78 of this chapter. Once the MRV plan is final and 

no longer subject to administrative appeal under part 78 of 

this chapter, you must implement the plan starting on the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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day after the day on which the plan becomes final and is no 

longer subject to such appeal.

(d) MRV plan revisions. You must revise and submit

the MRV plan within 180 days to the Administrator for 

approval if any of the following in paragraphs (d)(1) 

through (d)(4) of this section applies. You must include 

the reason(s) for the revisions in your submittal. 

(1) A material change was made to monitoring and/or 

operational parameters that was not anticipated in the 

original MRV plan. Examples of material changes include 

but are not limited to: large changes in the volume of CO2 

injected; the construction of new injection wells not 

identified in the MRV plan; failures of the monitoring 

system including monitoring system sensitivity, 

performance, location, or baseline; changes to surface land 

use that affects baseline or operational conditions; 

observed plume location that differs significantly from the 

predicted plume area used for developing the MRV plan; a 

change in the maximum monitoring area or active monitoring 

area; or a change in monitoring technology that would 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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result in coverage or detection capability different from 

the MRV plan. 

(2) A change in the permit class of your Underground 

Injection Control permit.

(3) If you are notified by EPA of substantive errors 

in your MRV plan or monitoring report.

(4) You choose to revise your MRV plan for any other 

reason in any reporting year. 

(e) Revised MRV plan. The requirements of paragraph 

(c) of this section apply to any submission of a revised 

MRV plan. You must continue reporting under your currently 

approved plan while awaiting approval of a revised MRV 

plan. 

(f) Format. Each proposed MRV plan or revision and 

each annual report must be submitted electronically in a 

format specified by the Administrator.

(g) Certificate of representation. You must submit a 

certificate of representation according to the provisions 

in §98.4 at least 60 days before submission of your MRV 

plan, your research and development exemption request, your 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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MRV plan submission extension request, or your initial 

annual report under this part, whichever is earlier.

§98.449 Definitions.

Except as provided below, all terms used in this 

subpart have the same meaning given in the Clean Air Act 

and subpart A of this part. 

Active monitoring area is the area that will be 

monitored over a specific time interval from the first year 

of the period (n) to the last year in the period (t). The 

boundary of the active monitoring area is established by 

superimposing two areas: 

(1) The area projected to contain the free phase CO2

plume at the end of year t, plus an all around buffer zone 

of one-half mile or greater if known leakage pathways 

extend laterally more than one-half mile.

(2) The area projected to contain the free phase CO2

plume at the end of year t+5. 

CO2 received means the CO2 stream that you receive to 

be injected for the first time into a well on your facility 

that is covered by this subpart. CO2 received includes, but 

is not limited to, a CO2 stream from a production process 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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unit inside your facility and a CO2 stream that was injected 

into a well on another facility, removed from a 

discontinued enhanced oil or natural gas or other 

production well, and transferred to your facility.

Equipment leak means those emissions that could not 

reasonably pass through a stack, chimney, vent, or other 

functionally-equivalent opening.

Expected baseline is the anticipated value of a 

monitored parameter that is compared to the measured 

monitored parameter. 

Maximum monitoring area means the area that must be 

monitored under this regulation and is defined as equal to 

or greater than the area expected to contain the free phase 

CO2 plume until the CO2 plume has stabilized plus an allaround buffer zone of at least one-half mile.

Research and development project means a project for 

the purpose of investigating practices, monitoring 

techniques, or injection verification, or engaging in other 

applied research, that will enable safe and effective longterm containment of a CO2 stream in subsurface geologic 

formations, including research and short duration CO2
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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injection tests conducted as a precursor to long-term 

storage.

Separator means a vessel in which streams of multiple 

phases are gravity separated into individual streams of 

single phase.

Surface leakage means the movement of the injected CO2 

stream from the injection zone to the surface, and into the 

atmosphere, indoor air, oceans, or surface water. 

Underground Injection Control permit means a permit 

issued under the authority of Part C of the Safe Drinking 

Water Act at 42 U.S.C. 300h et seq.

Underground Injection Control program means the 

program responsible for regulating the construction, 

operation, permitting, and closure of injection wells that 

place fluids underground for storage or disposal for 

purposes of protecting underground sources of drinking 

water from endangerment pursuant to Part C of the Safe 

Drinking Water Act at 42 U.S.C. 300h et seq.

Vented emissions means intentional or designed 

releases of CH4 or CO2 containing natural gas or hydrocarbon 

gas (not including stationary combustion flue gas), 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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including process designed flow to the atmosphere through 

seals or vent pipes, equipment blowdown for maintenance, 

and direct venting of gas used to power equipment (such as 

pneumatic devices).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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Subpart TT – Industrial Waste Landfills

§98.460 Definition of the source category.

(a) This source category applies to industrial waste 

landfills that accepted waste on or after January 1, 1980, 

and that are located at a facility whose total landfill 

design capacity is greater than or equal to 300,000 metric 

tons. 

(b) An industrial waste landfill is a landfill other 

than a municipal solid waste landfill, a RCRA Subtitle C

hazardous waste landfill, or a TSCA hazardous waste 

landfill, in which industrial solid waste, such as RCRA 

Subtitle D wastes (non-hazardous industrial solid waste, 

defined in 40 CFR 257.2), commercial solid wastes, or 

conditionally exempt small quantity generator wastes, is 

placed. An industrial waste landfill includes all disposal 

areas at the facility. 

(c) This source category does not include:

(1) Construction and demolition waste landfills. 

(2) Industrial waste landfills that only receive one 

or more of the following inert waste materials:
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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(i) Coal combustion or incinerator ash (e.g., fly 

ash).

(ii) Cement kiln dust.

(iii) Rocks and/or soil from excavation and 

construction and similar activities.

(iv) Glass.

(v) Non-chemically bound sand (e.g., green foundry 

sand).

(vii) Clay, gypsum, or pottery cull.

(viii) Bricks, mortar, or cement.

(ix) Furnace slag.

(x) Materials used as refractory (e.g., alumina, 

silicon, fire clay, fire brick).

(xi) Plastics (e.g., polyethylene, polypropylene,

polyethylene terephthalate, polystyrene, polyvinyl 

chloride).

(xii) Other waste material that has a volatile solids 

concentration of 0.5 weight percent (on a dry basis) or 

less. 

(d) This source category consists of the following 

sources at industrial waste landfills: Landfills, gas 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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collection systems at landfills, and destruction devices 

for landfill gases (including flares).

§98.461 Reporting threshold.

You must report GHG emissions under this subpart if 

your facility contains an industrial waste landfill meeting 

the criteria in §98.460 and the facility meets the 

requirements of §98.2(a)(2). For the purposes of 

§98.2(a)(2), the emissions from the industrial waste 

landfill are to be determined using the methane generation 

corrected for oxidation as determined using Equation TT-6

of this subpart times the global warming potential for 

methane in Table A-1 of subpart A of this part. 

§98.462 GHGs to report.

(a) You must report CH4 generation and CH4 emissions 

from industrial waste landfills.

(b) You must report CH4 destruction resulting from 

landfill gas collection and destruction devices, if 

present.

(c) You must report under subpart C of this part 

(General Stationary Fuel Combustion Sources) the emissions 

of CO2, CH4, and N2O from each stationary combustion unit 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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associated with the landfill gas destruction device, if 

present, by following the requirements of subpart C of this 

part. 

§98.463 Calculating GHG emissions.

(a) For each industrial waste landfill subject to the 

reporting requirements of this subpart, calculate annual 

modeled CH4 generation according to the applicable 

requirements in paragraphs (a)(1) through (a)(3) of this 

section. Apply Equation TT-1 of this section for each 

waste stream disposed of in the landfill and sum the CH4

generation rates for all waste streams disposed of in the 

landfill to calculate the total annual modeled CH4

generation rate for the landfill.

(1) Calculate annual modeled CH4 generation using 

Equation TT-1 of this section.

  























        





    

1

( 1) ( )

4

12

16 T

x S

k T x k T x

CH x x F G W DOC MCF DOC F e e (Eq. TT-1)

Where:

GCH4 = Modeled methane generation in reporting year T 

(metric tons CH4).

X = Year in which waste was disposed. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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S = Start year of calculation. Use the year 1960

or the opening year of the landfill, whichever 

is more recent. 

T = Reporting year for which emissions are 

calculated. 

Wx = Quantity of waste disposed in the industrial 

waste landfill in year X from measurement data 

and/or other company records (metric tons, as 

received (wet weight)). 

DOCx = Degradable organic carbon for waste disposed 

in year X from Table TT-1 of this subpart or 

from measurement data [as specified in 

paragraph (a)(3) of this section], if 

available [fraction (metric tons C/metric ton 

waste)]. 

DOCF = Fraction of DOC dissimilated (fraction); use 

the default value of 0.5. 

MCF = Methane correction factor (fraction). Use the 

default value of 1 unless there is active 

aeration of waste within the landfill during 

the reporting year. If there is active 

aeration of waste within the landfill during 

the reporting year, use either the default 

value of 1 or select an alternative value no 

less than 0.5 based on site-specific aeration 

parameters.

F = Fraction by volume of CH4 in landfill gas

(fraction, dry basis, corrected to 0% oxygen). 

If you have a gas collection system, use the 

annual average CH4 concentration from 

measurement data for the current reporting 

year; otherwise, use the default value of 0.5.

k = Decay rate constant from Table TT-1 of this 

subpart (yr-1). Select the most applicable k 

value for the majority of the past 10 years 

(or operating life, whichever is shorter).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(2) Waste stream quantities. Determine annual waste 

quantities as specified in paragraphs (a)(2)(i) through 

(ii) of this section for each year starting with January 1, 

1960 or the year the landfills first accepted waste if 

after January 1, 1960, up until the most recent reporting 

year. The choice of method for determining waste 

quantities will vary according to the availability of 

historical data. Beginning in the first emissions 

reporting year (2011 or later) and for each year 

thereafter, use the procedures in paragraph (a)(2)(i) of 

this section to determine waste stream quantities. These 

procedures should also be used for any year prior to the 

first emissions reporting year for which the data are 

available. For other historical years, use paragraph 

(a)(2)(i) of this section, where waste disposal records are 

available, and use the procedures outlined in paragraph 

(a)(2)(ii) of this section when waste disposal records are 

unavailable, to determine waste stream quantities. 

Historical disposal quantities deposited (i.e, prior to the 

first year in which monitoring begins) should only be 

determined once, as part of the first annual report, and 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

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the same values should be used for all subsequent annual 

reports, supplemented by the next year’s data on new waste 

disposal. 

(i) Determine the quantity of waste (in metric tons 

as received, i.e., wet weight) disposed of in the landfill 

separately for each waste stream by any one or a 

combination of the following methods.

(A) Direct mass measurements.

(B) Direct volume measurements multiplied by waste 

stream density determined from periodic density measurement 

data or process knowledge.

(C) Mass balance procedures, determining the mass of 

waste as the difference between the mass of the process 

inputs and the mass of the process outputs. 

(D) The number of loads (e.g., trucks) multiplied by 

the mass of waste per load based on the working capacity of 

the container or vehicle. 

(ii) Determine the historical disposal quantities for 

landfills using the Waste Disposal Factor approach in 

paragraphs (a)(2)(ii)(A) and (B) of this section when 

historical production or processing data are available. If 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 495 of 520

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production or processing data are available for a given 

year, you must use Equation TT-3 of this section for that 

year. Determine historical disposal quantities using the 

method specified in paragraph (a)(2)(ii)(C) of this section 

when historical production or processing data are not 

available, and for waste streams received from an off-site 

facility when historical disposal quantities cannot be 

determined using the methods specified in paragraph 

(a)(2)(i) of this section. 

(A) Determining Waste Disposal Factor: For each 

waste stream disposed of in the landfill, calculate the 

average waste disposal rate per unit of production or unit 

throughput using all available waste quantity data and 

corresponding production or processing rates for the 

process generating that waste or, if appropriate, the 

facility, using Equation TT-2 of this section. 



























 

2

1

Y

x Y x

x

N P

W

WDF (Eq. TT-2)

Where:

WDF = Average waste disposal factor as determined for the 

first annual report required for this industrial 

waste landfill (metric tons per production unit). 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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X = Year in which waste was disposed. Include only 

those years for which disposal and production data 

are both available; the years do not need to be 

sequential.

Y1 = First year in which disposal and 

production/throughput data are both available.

Y2 = First year for which GHG emissions from this 

industrial waste landfill must be reported.

N = Number of years for which disposal and 

production/throughput data are both available.

Wx = Quantity of waste placed in the industrial waste 

landfill in year X from measurement data and/or 

other company records (metric tons, as received 

(wet weight)).

Px = Quantity of product produced or feedstock entering 

the process or facility in year X from measurement 

data and/or other company records (production 

units). You must use the same basis for all years 

in the calculation. That is, Px must be determined 

based on production (quantity of product produced) 

for all “N” years or Px must be determined based on 

throughput (quantity of feedstock) for all “N” 

years.

(B) Calculate waste: For each waste stream disposed 

of in the landfill, calculate the waste disposal quantities 

for historic years in which direct waste disposal 

measurements are not available using historical production 

data and Equation TT-3 of this section. 

Wx  WDF  Px (Eq. TT-3)

Where:

X = Historic year in which waste was disposed.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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Wx = Calculated quantity of waste placed in the 

landfill in year X (metric tons).

WDF = Average waste disposal factor from Equation TT2 of this section (metric tons per production 

unit).

Px = Quantity of product produced or feedstock 

entering the process or facility in year X from 

measurement data and/or other company records

(production units). You must use the same basis 

for Px (either production only or throughput 

only) as used to determine WDF in Equation TT-2 

of this section. 

(C) For any year in which historic production or 

processing data are not available such that historic waste 

quantities cannot be estimated using Equation TT-3 of this 

section, calculate an average annual bulk waste disposal 

quantity using Equation TT-4 of this section. 

  1



YrData YrOpen

LFC Wx (Eq. TT-4)

Where:

Wx = Quantity of waste placed in the landfill in year 

X (metric tons, wet basis). This annual bulk 

waste disposal quantity applies for all years 

from “YrOpen” to “YrData” inclusive.

LFC = Capacity of the landfill used (or the total 

quantity of waste-in-place) at the end of the 

“YrData” from design drawings or engineering 

estimates (metric tons). For closed landfills 

for which waste quantity data are not available, 

use the landfill’s design capacity.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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YrData = The year prior to the year when waste disposal 

data are first available from company records or 

from Equation TT-3 of this section. For 

landfills for which waste quantity data are not 

available, the year in which the landfill last 

received waste.

YrOpen = Year 1960 or the year in which the landfill 

first received waste from company records, 

whichever is more recent. If no data are 

available for estimating YrOpen for a closed 

landfill, use 1960 as the default “YrOpen” for 

the landfill. 

(3) Degradable organic content (DOC). For any year, 

X, in Equation TT-1 of this section, use either the 

applicable default DOC values provided in Table TT-1 of 

this subpart or determine values for DOCx as specified in 

paragraphs (a)(3)(i) through (iv) of this section. When 

developing historical waste quantity data, you may use 

default DOC values from Table TT-1 of this subpart for 

certain years and determined values for DOCx for other 

years. The historical values for DOC or DOCx must be 

developed only for the first annual report required for the 

industrial waste landfill; and used for all subsequent 

annual reports (e.g., if DOC for year x=1990 was determined 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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to be 0.15 in the first reporting year, you must use 0.15 

for the 1990 DOC value for all subsequent annual reports). 

(i) For the first year in which GHG emissions from 

this industrial waste landfill must be reported, determine 

the DOCx value of each waste stream disposed of in the 

landfill no less frequently than once per quarter using the 

methods specified in §98.464(b). Calculate annual DOCx for 

each waste stream as the arithmetic average of all DOCx

values for that waste stream that were measured during the 

year.

(ii) For subsequent years (after the first year in 

which GHG emissions from this industrial waste landfill 

must be reported), either use the DOCx of each waste stream 

calculated for the most recent reporting year for which DOC 

values were determined according to paragraph (a)(3)(i) of 

this section, or determine new DOC values for that year 

following the requirements in paragraph (a)(3)(i) of this 

section. You must determine new DOC values following the 

requirements in paragraph (a)(3)(i) of this section if 

changes in the process operations occurred during the 

previous reporting year that can reasonably be expected to 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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alter the characteristics of the waste stream, such as the 

water content or volatile solids concentration. Should 

changes to the waste stream occur, you must revise the GHG 

Monitoring Plan as required in §98.3(g)(5)(iii) and report 

the new DOCx value according to the requirements of §98.466.

(iii) If DOCx measurement data for each waste stream 

are available according to the methods specified in 

§98.464(b) for years prior to the first year in which GHG 

emissions from this industrial waste landfill must be 

reported, determine DOCx for each waste stream as the 

arithmetic average of all DOCx values for that waste stream 

that were measured in Year X. A single measurement value 

is acceptable for determining DOCx for years prior to the 

first reporting year.

(iv) For historical years for which DOCx measurement 

data, determined according to the methods specified in 

§98.464(b), are not available, determine the historical 

values for DOCx using the applicable methods specified in 

paragraphs (a)(3)(iv)(A) and (B) of this section.

Determine these historical values for DOCx only for the 

first annual report required for this industrial waste 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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landfill; historical values for DOCx calculated for this 

first annual report should be used for all subsequent 

annual reports.

(A) For years in which waste stream-specific disposal 

quantities are determined (as required in paragraphs (a)(2) 

(ii)(A) and (B) of this section), calculate the average DOC 

value for a given waste stream as the arithmetic average of 

all DOC measurements of that waste stream that follow the 

methods provided in §98.464(b), including any measurement 

values for years prior to the first reporting year and the 

four measurement values required in the first reporting 

year. Use the resulting waste-specific average DOC value 

for all applicable years (i.e., years in which waste

stream-specific disposal quantities are determined) for 

which direct DOC measurement data are not available. 

(B) For years for which bulk waste disposal 

quantities are determined according to paragraphs 

(a)(2)(ii)(C) of this section, calculate the weighted 

average bulk DOC value according to the following: 

calculate the average DOC value for each waste stream as 

the arithmetic average of all DOC measurements of that 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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waste stream that follows the methods provided in 

§98.464(b) (generally, this will include only the DOC 

values determined in the first year in which GHG emissions 

from this industrial waste landfill must be reported); 

calculate the average annual disposal quantity for each 

waste stream as the arithmetic average of the annual 

disposal quantities for each year in which waste streamspecific disposal quantities have been determined; and 

calculate the bulk waste DOC value using Equation TT-5 of 

this section. Use the bulk waste DOC value as DOCx for all 

years for which bulk waste disposal quantities are 

determined according to paragraphs (a)(2)(ii)(C) of this 

section. 

 











 N

n

ave n

N

n

ave n ave n

bulk

W

DOC W

DOC

1

,

1

, ,

(Eq. TT-5)

Where:

DOCbulk = Degradable organic content value for bulk 

historical waste placed in the landfill (mass 

fraction).

N = Number of different waste streams placed in the 

landfill

n = Index for waste stream
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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DOCave,n = Average degradable organic content value for 

waste stream “n” based on available measurement 

data (mass fraction).

Wave,n = Average annual quantity of waste stream “n” 

placed in the landfill for years in which waste 

stream-specific disposal quantities have been 

determined (metric tons per year, wet basis).

(b) For each landfill, calculate CH4 generation 

(adjusted for oxidation in cover materials) and CH4

emissions (taking into account any CH4 recovery, if 

applicable, and oxidation in cover materials) according to 

the applicable methods in paragraphs (b)(1) through (b)(3) 

of this section.

(1) For each landfill, calculate CH4 generation, 

adjusted for oxidation, from the modeled CH4 (GCH4 from 

Equation TT-1 of this section) using Equation TT-6 of this 

section.

MG G (1- OX)  CH4  (Eq. TT-6)

Where: 

MG = Methane generation, adjusted for oxidation, from the 

landfill in the reporting year (metric tons CH4).

GCH4 = Modeled methane generation rate in reporting year 

from Equation TT-1 of this section (metric tons 

CH4).
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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OX = Oxidation fraction. Use the default value of 0.1 

(10 percent).

(2) For landfills that do not have landfill gas 

collection systems operating during the reporting year, the

CH4 emissions are equal to the CH4 generation (MG) 

calculated in Equation TT-6 of this section.

(3) For landfills with landfill gas collection 

systems in operation during any portion of the reporting 

year, perform all of the calculations specified in 

paragraphs (b)(3)(i) through (iv) of this section.

(i) Calculate the quantity of CH4 recovered according 

to the requirements at §98.343(b).

(ii) Calculate CH4 emissions using the Equation HH-6 

of §98.343(c)(3)(i), except use GCH4 determined using 

Equation TT-1 of this section in Equation HH-6 of 

§98.343(c)(3)(i).

(iii) Calculate CH4 generation (MG) from the quantity 

of CH4 recovered using Equation HH-7 of §98.343(c)(3)(ii).

(iv) Calculate CH4 emissions from the quantity of CH4

recovered using Equation HH-8 of §98.343(c)(3)(ii).

§98.464 Monitoring and QA/QC requirements. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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(a) For calendar year 2011 monitoring, the facility

may submit a request to the Administrator to use one or 

more best available monitoring methods as listed in 

§98.3(d)(1)(i) through (iv). The request must be submitted 

no later than [INSERT DATE 90 DAYS AFTER PUBLICATION IN THE 

FEDERAL REGISTER] and must contain the information in 

§98.3(d)(2)(ii). To obtain approval, the request must 

demonstrate to the Administrator’s satisfaction that it is 

not reasonably feasible to acquire, install, and operate a 

required piece of monitoring equipment by January 1, 2011. 

The use of best available monitoring methods will not be 

approved beyond December 31, 2011. 

(b) For each waste stream received during the 

reporting year for which you choose to determine volatile 

solids concentration for the purposes of paragraph 

§98.460(c)(2)(xii) or choose to determine a landfillspecific DOCx for use in Equation TT-1 of this subpart, you 

must collect and test a representative sample of that waste 

stream using the methods specified in paragraphs (b)(1) 

through (b)(4) of this section.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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(1) Develop and follow a sampling plan to collect a 

representative sample of each waste stream (as received at 

the landfill) for which testing is elected.

(2) Determine the percent total solids and the 

percent volatile solids of each sample following Standard 

Method 2540G “Total, Fixed, and Volatile Solids in Solid 

and Semisolid Samples” (incorporated by reference; see

§98.7). 

(3) For the purposes of paragraph §98.460(c)(2)(xii), 

the volatile solids concentration (weight percent on a dry 

basis) is the percent volatile solids determined using 

Standard Method 2540G “Total, Fixed, and Volatile Solids in 

Solid and Semisolid Samples” (incorporated by reference; 

see §98.7).

(4) Calculate the waste stream-specific DOCx value 

using Equation TT-7 of this section.

 

100%

% TotalSolids

100%

% VolatileSolids DOC F

x x

x  DOC   (Eq. TT-7) 

Where: 

DOCx = Degradable organic content of waste 

stream in Year X (weight fraction, wet 

basis)
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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FDOC = Fraction of the volatile residue that 

is degradable organic carbon (weight 

fraction). Use a default value of 0.6.

% Volatile Solidsx = Percent volatile solids determined 

using Standard Method 2540G Total, 

“Fixed, and Volatile Solids in Solid 

and Semisolid Samples” (incorporated by 

reference; see §98.7) for Year X

[milligrams (mg) volatile solids per 

100 mg dried solids].

% Total Solidsx = Percent total solids determined using 

Standard Method 2540G “Total, Fixed, 

and Volatile Solids in Solid and 

Semisolid Samples” (incorporated by 

reference; see §98.7) for Year X (mg 

dried solids per 100 mg wet waste).

(c) For each waste stream for which you choose to 

determine volatile solids concentration for the purposes of 

paragraph §98.460(c)(2)(xii), and that was historically 

managed in the landfill but was not received during the 

first reporting year, you must determine volatile solids 

concentration of the waste stream as initially placed in 

the landfill using the methods specified in paragraph 

(c)(1) or (c)(2) of this section, as applicable.

(1) If you can identify a similar waste stream to the 

waste stream that was historically managed in the landfill, 

you must determine the volatile solids concentration of the 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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similar waste stream using the procedures in paragraphs 

(b)(1) through (b)(3) of this section.

(2) If you cannot identify a similar waste stream to 

the waste stream that was historically managed in the 

landfill, you may determine the volatile solids 

concentration of the historically managed waste stream 

using process knowledge. You must document the basis for 

volatile solids concentration as determined through process 

knowledge. 

(d) For landfills with gas collection systems, 

operate, maintain, and calibrate a gas composition monitor 

capable of measuring the concentration of CH4 according to 

the requirements specified at §98.344(b).

(e) For landfills with gas collection systems, 

install, operate, maintain, and calibrate a gas flow meter 

capable of measuring the volumetric flow rate of the 

recovered landfill gas according to the requirements

specified at §98.344(c). 

(f) For landfills with gas collection systems, all 

temperature, pressure, and if applicable, moisture content 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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monitors must be calibrated using the procedures and 

frequencies specified by the manufacturer.

(g) For landfills electing to measure the fraction by 

volume of CH4 in landfill gas (F), follow the requirements 

in paragraphs (g)(1) and (g)(2) of this section. 

(1) Use a gas composition monitor capable of 

measuring the concentration of CH4 on a dry basis that is 

properly operated, calibrated, and maintained according to 

the requirements specified at §98.344(b). You must either 

use a gas composition monitor that is also capable of 

measuring the O2 concentration correcting for excess 

(infiltration) air or you must operate, maintain, and 

calibrate a second monitor capable of measuring the O2

concentration on a dry basis according to the 

manufacturer’s specifications. 

(2) Use Equation TT-8 of this section to correct the 

measured CH4 concentration to 0% oxygen. If multiple CH4

concentration measurements are made during the reporting 

year, determine F separately for each measurement made 

during the reporting year, and use the results to determine 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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the arithmetic average value of F for use in Equation TT-1 

of this part. 

 























2

4

20.9 %

20.9

100% O

C

F

CH c (Eq. TT-8)

Where:

F = Fraction by volume of CH4 in landfill gas (fraction, 

dry basis, corrected to 0% oxygen);

CCH4 = measured CH4 concentration in landfill gas (volume 

%, dry basis);

20.9c = defined O2 correction basis, (volume %, dry basis);

20.9 = O2 concentration in air (volume %, dry basis); and

%O2 = measured O2 concentration in landfill gas (volume %, 

dry basis).

(h) The facility shall document the procedures used to 

ensure the accuracy of the estimates of disposal quantities 

and, if the industrial waste landfill has a gas collection 

system, gas flow rate, gas composition, temperature, 

pressure, and moisture content measurements. These 

procedures include, but are not limited 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.

§98.465 Procedures for estimating missing data.
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document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

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(a) A complete record of all measured parameters used 

in the GHG emissions calculations is required. Therefore, 

whenever a quality-assured value of a required parameter is 

unavailable (e.g., if a meter malfunctions during unit 

operation or if a required fuel sample is not taken), a 

substitute data value for the missing parameter shall be 

used in the calculations, in accordance with paragraph (b) 

of this section.

(b) For industrial waste landfills with gas 

collection systems, follow the procedures for estimating 

missing data specified in §98.345(a) and (b).

§98.466 Data reporting requirements. 

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

each annual report must contain the following information 

for each landfill. 

(a) Report the following general landfill 

information: 

(1) A classification of the landfill as “open” 

(actively received waste in the reporting year) or “closed” 

(no longer receiving waste). 
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not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

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(2) The year in which the landfill first started 

accepting waste for disposal. 

(3) The last year the landfill accepted waste (for 

open landfills, enter the estimated year of landfill 

closure). 

(4) The capacity (in metric tons) of the landfill.

(5) An indication of whether leachate recirculation 

is used during the reporting year and its typical frequency 

of use over the past 10 years (e.g., used several times a 

year for the past 10 years, used at least once a year for 

the past 10 years, used occasionally but not every year 

over the past 10 years, not used).

(b) Report the following waste characterization and 

modeling information:

(1) The number of waste steams (including “Other 

Industrial Solid Waste (not otherwise listed)”) for which 

Equation TT-1 of this subpart is used to calculate modeled 

CH4 generation.

(2) A description of each waste stream (including the 

types of materials in each waste stream) for which Equation 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 513 of 520

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TT-1 of this subpart is used to calculate modeled CH4

generation.

(3) The fraction of CH4 in the landfill gas, F,

(volume fraction, dry basis, corrected to 0% oxygen) for 

the reporting year and an indication as to whether this was 

the default value or a value determined through measurement 

data. 

(4) The methane correction factor (MCF) value used in 

the calculations. If an MCF value other than the default 

of 1 is used, provide a description of the aeration system, 

including aeration blower capacity, the fraction of the 

landfill containing waste affected by the aeration, the 

total number of hours during the year the aeration blower 

was operated, and other factors used as a basis for the 

selected MCF value.

(c) For each waste stream identified in paragraph (b) 

of this section, report the following information:

(1) The decay rate (k) value used in the 

calculations. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(2) The method(s) for estimating historical waste 

disposal quantities and the range of years for which each 

method applies. 

(3) If Equation TT-2 of this subpart is used, 

provide: 

(i) The total number of years (N) for which disposal 

and production data are both available. 

(ii) The year, the waste disposal quantity and 

production quantity for each year used in Equation TT-2 of 

this subpart to calculate the average waste disposal factor 

(WDF).

(iii) The average waste disposal factor (WDF) 

calculated for the waste stream. 

(4) If Equation TT-4 of this subpart is used, 

provide:

(i) The value of landfill capacity (LFC).

(ii) YrData. 

(iii) YrOpen. 

(d) For each year of landfilling starting with the 

“Start Year” (S) and each year thereafter up to the current 

reporting year, report the following information:
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(1) The calendar year for which the following data 

elements apply. 

(2) The quantity of waste (Wx) disposed of in the 

landfill (metric tons, wet weight) for the specified year

for each waste stream identified in paragraph (b) of this 

section.

(3) The degradable organic carbon (DOCx) value (mass 

fraction) for the specified year and an indication as to 

whether this was the default value from Table TT-1 of this 

subpart or a value determined through sampling and 

calculation for each waste stream identified in paragraph 

(b) of this section. 

(e) Report the following information describing the 

landfill cover material:

(1) The type of cover material used (as either 

organic cover, clay cover, sand cover, or other soil 

mixtures). 

(2) For each type of cover material used, the surface 

area (in square meters) at the start of the reporting year 

for the landfill sections that contain waste and that are 

associated with the selected cover type. 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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(f) The modeled annual methane generation (GCH4) for 

the reporting year (metric tons CH4) calculated using 

Equation TT-1 of this subpart.

(g) For landfills without gas collection systems, 

provide:

(1) The annual methane emissions (i.e., the methane 

generation (MG), adjusted for oxidation, calculated using 

Equation TT-6 of this subpart), reported in metric tons CH4. 

(2) 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 this landfill.

(h) For landfills with gas collection systems, in 

addition to the reporting requirements in paragraphs (a) 

through (f) of this section, you must report according to 

§98.346(i). 

§98.467 Records that must be retained. 

In addition to the information required by §98.3(g), 

you must retain the calibration records for all monitoring 

equipment, including the method or manufacturer’s 

specification used for calibration, and all total and 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 517 of 520

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volatile solids concentration measurement data used for the 

purposes of paragraph §98.460(c)(2)(xii) or used to 

determine landfill-specific DOCx values. 

§98.468 Definitions.

Except as provided below, all terms used in this 

subpart have the same meaning given in the CAA and subpart 

A of this part.

Construction and demolition (C&D) waste landfill means 

a solid waste disposal facility subject to the requirements 

of subparts A or B of part 257 of this chapter that 

receives construction and demolition waste and does not 

receive hazardous waste (defined in § 261.3 of this 

chapter) or industrial solid waste (defined in § 258.2 of 

this chapter) or municipal solid waste (defined in § 98.6 

of this part) other than residential lead-based paint 

waste. A C&D waste landfill typically receives any one or 

more of the following types of solid wastes: roadwork 

material, excavated material, demolition waste, 

construction/renovation waste, and site clearance waste.

Design capacity means the maximum amount of solid 

waste a landfill can accept, as indicated in terms of 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

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volume or mass in the most recent permit issued by the 

State, local, or Tribal agency responsible for regulating 

the landfill, plus any in-place waste not accounted for in 

the most recent permit. If the owner or operator chooses 

to convert the design capacity from volume to mass to 

determine its design capacity, the calculation must include 

a site specific density, which must be recalculated 

annually.

Solid waste has the meaning established by the 

Administrator pursuant to the Solid Waste Disposal Act (42 

U.S.C.A. 6901 et seq.).

Waste stream means industrial solid waste material 

that is generated by a specific manufacturing process or 

client. For wastes generated at the facility that includes 

the industrial waste landfill, a waste stream is the 

industrial solid waste material generated by a specific 

processing unit at that facility. For industrial solid 

wastes that are received from off-site facilities, a waste 

stream can be defined as each waste shipment or group of 

waste shipments received from a single client or group of 
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 519 of 520

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clients that produce industrial solid wastes with similar 

waste properties.

Table TT-1 of Subpart TT—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 0.22 0.06 0.12 0.18

Pulp and Paper 0.20 0.02 0.03 0.04

Wood and Wood Product 0.43 0.02 0.03 0.04

Construction and Demolition 0.08 0.02 0.03 0.04

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

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.
DRAFT -- This draft only contains redline/strikeout text. This 

document is provided solely for informational purposes. It does 

not provide legal advice, have legally binding effect, or 

expressly or implicitly create, expand, or limit any legal 

rights, obligations, responsibilities, expectations, or benefits 

in regard to any person. The purpose of this redline is to 

facilitate public review of the 2011 Technical Corrections, 

Clarifying and Other Amendments to the Mandatory Reporting of 

Greenhouse Gases Rule. 

Page 520 of 520

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